20150827Application & Exhibits.pdf

Avista Corp.
1411 East Mission P.O.Box3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
August 26,2015
State of Idaho
Idaho Public Utilities Commission
47 2 W. Washington Street
Boise, Idaho 83702-5983
AfrYtsrt
CW
:l,i
Case No. AVU-G-I5-02- /Advice No. 15-01-G
Attention: Ms. Jean D. Jewell
I.P.U.C. No. 27 - Natural Gas Service
Enclosed for filing with the Commission are the following revised tariff sheets:
Twenty-first Revision Sheet 150 canceling Twentieth Revision Sheet 150
Seventeenth Revision Sheet 155 canceling Sixteenth Revision Sheet 155
The Company requests that the proposed tariff sheets be made effective November 1,2015.
These tariff sheets reflect the Company's annual Purchased Gas Cost Adjustment ("PGA"). If
approved, the Company's annual revenue will decrease by approximately $10.3 million or
approximately 14.5o/o. The proposed changes have no effect on the Company's eamings. Detailed
information related to the Company's request is included in the attached Application and supporting
workpapers.
If the Company's request is approved, a residential or small commercial customer using an average
of 61 therms per month will see decrease of $7.94 per month, or approximately 13.4%o. The present
bill for 61 therms is$59.22 while the proposed bill is 551.28. The Company will issue a notice to its
customers through a bill insert starting on or about September 3,2015 and ending on or about
October 2,2015. A copy of the bill insert has been included in the Company's frling.
If you have any questions regarding this filing, please contact Patrick Ehrbar at [phone] or
Ryan Finesilver at [phone].
Sincerely,
fl//-D6vifJ. Meyer
Vice President and Chief Counsel for Regulatory and Governmental Affairs
Enclosures
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that I have served Avista Corporation dba Avista Utilities' Advice
filing ADV 15-01-G (Tariff IPUC No. 27 Natural Gas Service) by mailing a copy thereof,
postage prepaid to the following:
Jean D Jewell, Secretary
ldaho Public Utilities Commission
472 W . Washington Street
Boise, lD 83720-5983
Chad Stokes
Cable Huston Benedict Haagensen &
Lloyd, LLP
1001 SW 5th, Suite 2000
Portland, OR 97204-1136
Edward A. Finklea
Northwest lndustrial Gas Users
326 Fifth Street
Lake Oswego, OR 97034
Curt Hibbard
St. Joseph Regional Medical Center
PO Box 816
Lewiston, ID 83501
fttA\t Spokane, Washington this 26th day of August 2015.
Patrick Ehrbar
Manager, State & Federal Regulation
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION OF )
AVISTA UTILITIES FOR AN ORDER APPROVING ) CASE: AVU-G-15 -07-
A CHANGE IN NATURAL GAS RATES AND CHARGES )
Application is hereby made to the Idaho Public Utilities Commission for an Order approving a revised
schedule of rates and charges for natural gas service in the state of Idaho. The Applicant requests that
the proposed rates included in this Purchased Gas Cost Adjustment ("PGA") filing be made effective
on November 1, 2015. If approved as filed, the Company's annual revenue will decrease by
approximately 510.3 million or about 14.5%. In support of this Application, Applicant states as
follows:
I.
The name of the Applicant is AVISTA CORPORATION, doing business as AVISTA UTILITIES
(hereinafter Avista, Applicant or Company), a Washington corporation, whose principal business
office is l4l1 East Mission Avenue, Spokane, Washington, and is qualified to do business in the state
of tdaho. Applicant maintains district ofhces in Moscow, Lewiston, Coeur d'Alene, and Kellogg,
Idaho. Communications in reference to this Application should be addressed to:
Kelly O. Norwood
Vice President of State & Federal Regulation
Avista Utilities
1411 E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
Kelly.norwood@avi stacorp. com
il.
Attorney for the Applicant and his address is as follows:
David J. Meyer
Vice President and Chief Counsel for Regulatory
And Governmental Affairs
Avista Utilities
l41l E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
David.meyer@avistacorp. com
m.
The Applicant is a public utility engaged in the distribution of natural gas in certain portions of
Northem Idaho, Eastem and Central Washington, and Southwestern and Northeastern Oregon, and
further engaged in the generation, transmission, and distribution of electricity in Northern Idaho and
Eastern Washington.
ry.
Twenty-first Revision Sheet 150, which Applicant requests the Commission approve, is filed herewith
as Exhibit "A". Additionally, Seventeenth Revision Sheet 155, which Applicant requests the
Commission approve, is also filed herewith as Exhibit "A". Also included in Exhibit 'rA'r is a copy of
Twenty-first Revision Sheet 150 and Seventeenth Revision Tariff Sheet 155 with the changes
underlined and a copy of Twentieth Revision Sheet 150 and Sixteenth Revision Tariff Sheet 155 with
the proposed changes shown by lining over the current language or rates.
V.
The existing rates and charges for natural gas service on file with the Commission and designated as
Applicant's Tariff IPUC No. 27, which will be superseded by the rates and charges filed herewith, are
incorporated herein as though fully attached hereto.
u.
Notice to the Public of Applicant's proposed tariffs is to be given simultaneously with the filing of this
Application by posting, at each of the Company's district offices in Idaho, a Notice in the form
attached hereto as Exhibit "B" and by means of a press release distributed to various informational
agencies, a draft copy attached hereto in Exhibit "E". In addition, Exhibit "E" to this Application also
contains the form of customer notice that the Company will send to its customers in its monthly bills
starting on or about September 3,2015 and will end on or about October 2,2015.
VII.
The circumstances and conditions relied on for approval of Applicant's revised rates are as follows:
Applicant purchases natural gas for customer usage and transports it over Williams Northwest
Pipeline, Gas Transmission Northwest (GTN), TransCanada - Alberta, TransCanada - BC and Spectra
Energy Pipeline systems, and defers the effect of timing differences due to implementation of rate
changes and differences between Applicant's actual weighted average cost of gas ("WACOG")
purchased and the WACOG embedded in rates. Applicant also defers various pipeline refunds or
charges and miscellaneous revenue received from natural gas related transactions including pipeline
capacity releases.
VIII.
This filing reflects the Company's proposed annual PGA to: l) pass through changes in the estimated
cost of natural gas for the November 2015 through October 2016 twelve-month period (Schedule 150),
and 2) revise the amortization rate(s) to refund or collect the balance of deferred gas costs (Schedule
155). Below is a table summaizingthe proposed changes reflected in this filing.
Service
General
Lg. General
Interruptible
Sch.
No.
l0l
llr
13l
Commodity
Change
per therm
$ (0.13312)
$ (0.13312)
$ (0.13312)
Demand
Change
oer therm
$ 0.00133
$ 0.00133
S-
Total
Sch.150
Change
$ (0.1317e)
$ (0.1317e)
$ (0.13312)
Amortization
Change
per therm
s 0.00170
$ 0.00170
s (o.o2oe7)
Total Rate
Change
per therm
$ (0.1300e)
$ (0.1300e)
$ (0.1540e)
Overall
Perrent
Change
-13.4"h
-18.00
-24.60/"
Ix.
Commoditv Costs
As shown in the table above, the estimated WACOG change is a decrease of 13.31 cents per therm.
The proposed WACOG, including the revenue conversion factor, is 25.2 cents per therm compared to
the present WACOG of 38.5 cents per therm included in rates.
The winter of 2014-2015 was significantly warmer than normal both in the western United States and
nationally. The warmer than normal weather led to a decrease in overall natural gas demand and
reduced wholesale natural gas prices in the winter and spring. The downward pressure on wholesale
prices has continued even after the winter period due to the abundance of natural gas in storage and
continued high natural gas production levels.
The Company's natural gas Procurement Plan ("Plan") uses a diversified approach to procure natural
gas for the coming PGA year. While the Plan generally incorporates a more structured approach for
the hedging portion of the portfolio, the Company exercises flexibility and discretion in all areas of the
plan based on changes in the wholesale market. The Company typically meets with Commission Staff
semi-annually to discuss the state of the wholesale market and the status of the Company's Plan. In
addition, the Company communicates with Staff when it believes it makes sense to deviate from its
Plan and/or opportunities arise in the market.
Avista has been hedging natural gas on both a periodic and discretionary basis throughout 2014-2015
for the forthcoming PGA year (twelve months). Approximately 43Yo of estimated annual load
requirements for the PGA year (I.{ovember 2015 through October 2016) will be hedged at a fixed-price
derived from the Company's Plan. These volumes are comprised of: I) 12% of volumes hedged for a
term of one year or less, 2) 3l% of volumes from prior multi-year hedges. Through June, the planned
hedge volumes for the PGA year have been executed at a weighted average price of $3.32 per
dekatherm ($0.332 per therm).
The Company has approximately 920,000 dekatherms of underground storage capacity at Jackson
Prairie. As of June 30, 2015 approximately 412,000 dekatherms of this capacity is available to serve
peak day needs with the remaining 508,000 dekatherms being utilized to capture financial benefits for
customers associated with optimizing the use of Jackson Prairie by locking in price differentials
between time periods.' Approximately $2.2 million in net storage optimization benefits have been
included in this filing. The storage WACOG associated with withdrawal costs as of June 30,2015 for
all remaining storage volumes (providing 4.Yo of annual load requirements) is $2.37 per dekatherm
($0.237 per therm).
'Details regarding the storage optimization plan were provided to Staffin a previous communication on June 25,2015.
The Company has included known optimization benefits in this filing, and will pass through to customers the net benefits of
future storage optimization transactions in its next PGA.
The Company used a 30-day historical average of forward prices and supply basins (ending July 15,
2015) to develop an estimated cost associated with index purchases. The estimated monthly volumes
to be purchased by basin are multiplied by the 30-day average forward price for the corresponding
month and basin. These index purchases represent approximately 53Yo of estimated annual load
requirements for the coming year. The annual weighted average price for these volumes is $2.50 per
dekatherm ($0.25 per therm).
x.
Demand Costs
Demand costs primarily represent the cost of transporting natural gas on interstate pipelines to the
Company's local distribution system. As shown in the table above, there is a slight increase in the
overall demand rate of $0.00133 per therm for Schedules 101 and lll. Included in the Company's
filing are the new rates for TransCanada-Gas Transmission Northwest (GTN) which will go into effect
January 1,2016.
Schedule 155 / Amortization Rate Chanee
As shown in the table above, the proposed amortization rate change for Schedule l0l and Schedule
111 is a rate increase of $0.00170 per therm. The current rate applicable to Schedule 101 and Schedule
111 is $0.03056 per therm in the rebate direction; the proposed rate is $0.02886 per therm also in the
rebate direction. Contributing to the proposed amortization rebate rate are the effects of wholesale
natural gas prices that were lower than the level approved in the Company's 2014 PGA. As a result of
the lower prices, the amount of revenue collected from customers exceeded the Company's costs.
However, a portion of the benefit of reduced wholesale natural gas prices was offset by an under
collection of fixed demand costs which was the result of a warmer than normal winter.
xI.
If approved as filed, the Company's annual revenue will deuease by approximately S10.3 million or
about 14.5% effective November l, 2015. Residential or small commercial customers using an
average of 61 therms per month would see adecrease of $7.94 per month, or approximately l3.4Yo.
The present bill for 6l therms is$.59.22 while the proposed bill is $51.28.
XIII.
Exhibit "C" attached hereto contains support workpapers for the rates proposed by Applicant contained
in Exhibit "A".
xIV.
Avista requests that the rates proposed in this filing be approved to become effective on November 1,
2015, and requests that the matter be processed under the Commission's Modified Procedure rules
through the use of written comments. Avista stands ready for immediate consideration on its
Application.
xt.
xv.
WHEREFORE, Avista requests the Commission issue its Order finding its proposed rates to be just
reasonable, and nondiscriminatory and to become effective for all natural gas service on and after
November 1,2015.
Dated at Spokane, Washington, this 26n day of August 2015.
AVISTA UTILITIES
BY
Vice President and Chief Counsel for
VERIFICATION
STATE OF WASHINGTON )
)
County of Spokane )
David J. Meyer, being first duly sworn on oath, deposes and says: That he is the Vice President
and Chief Counsel for Regulatory and Govemmental Affairs of Avista Utilities and makes this
verification for and on behalf of Avista Corporation, being thereto duly authoized;
That he has read the foregoing filing, knows the contents thereof, and believes the same to be true.
SIGNED AND SWORN to before me this 26h day of August z}ls,by David J. Meyer
.t*."$[#".92
=S i8 trolenr -di
==-
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'4msli$Commission Expires:irlrclur
NOTARYPUBLIC in and for the State of
Washinglon, residing at Spokane.
AVISTA UTILITIES
Case No. AVU-G-I5-0>
EXHIBIT O'A"
Proposed Tariff Sheets
August 26,2015
l.P.U.C. No.27
Twenty-First Revision Sheet 150
Replacing
Twentieth Revision Sheet 150 150
AVISTA CORPORATION
d/bia Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
naturalgas, to become effective as noted below.
RATE:(a) The retail rates of firm gas Schedules 101, 111 and 112 are to be
increased by 36.1076 per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
25.198i, per therm.
(c) The rate for transportation under Schedule 146 is to be decreased by
0.0006 per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 101 10.909d 25J980, 36.1070,
Schedules 111 and 112 10.9096 25.1980, 36107A
Schedules 131 and 132 0.0000 25J980, 25.1980,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 10'1 10.8550 25.072i, 35.9270,
Schedules 111 and 112 10.8550 25.072Q, 35.9270
Schedules 131 and 132 0.0000 25.0720, 25.072i,
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company will maintain a Purchase Gas Adjustment (PGA) Balancing
Account whereby monthly entries into this Balancing Account will be made to reflect
differences between the actual purchased gas costs collected from customers and the
actual purchased gas costs incurred by the Company. Those differences are then
collected from or refunded to customers under Schedule 155 - Gas Rate Adjustment.
lssued August 26,2015 Effective November1,2015
lssued by Avista UtilitiesWZ.llr r/^"ra*elly O. Norwood - Vice-President, State & Federal Regulation
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT . IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
natural gas, to become effective as noted below.
RATE:(a) The retail rates of firm gas Schedules 101, 111 and 112 are to be
increased by 36.1070 per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
25.198i, per therm.
(c) The rate for transportation under Schedule 146 is to be decreased by
0.000d per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 101 10.9090 25j980, 36.1070
Schedules 111 and 112 10.9090 25.198i, 36.1070,
Schedules 131 and 132 0.000d 25.1980, 25.1980,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.855d 25.0720, 35.9270,
Schedules 111 and 112 10.8550 25.0720, 35.9270,
Schedules 131 and 132 0.000d 25.0720, 25.0720,
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company will maintain a Purchase Gas Adjustment (PGA) Balancing
Account whereby monthly entries into this Balancing Account will be made to reflect
differences between the actual purchased gas costs collected from customers and the
actual purchased gas costs incurred by the Company. Those differences are then
collected from or refunded to customers under Schedule 155 - Gas Rate Adjustment.
l.P.U.C. No.27
Twentv-First Revision Sheet 150
Replacing
Twentieth Revision Sheet 150 150
Kelly O. Norwood - Vice-President, State & Federal Regulation
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
natural gas, to become effective as noted below.
RATE:(a) The retail rates of firm gas Schedules 101, 111 and 112 are to be
increased by 49+86{ per therm in all blocks of these rate schedules.
(b) The rates of intenuptible Schedules 131 and 132 are to be increased by
3854eS per therm.
(c) The rate for transportation under Schedule 146 is to be decreased by
0.0000 per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 101 14J1.6+ 3&51e0 W
Schedules 111 and 112 1Uf4$ 3€=519d W
Schedules 131 and 132 0.0000 3&5100 38-5{e0
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 1g#+O WO 4€S330
schedutes 111 and 112 WO 383+20 WO
Schedules 131 and 132 0.0000 383+20 W
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company will maintain a Purchase Gas Adjustment (PGA) Balancing
Account whereby monthly entries into this Balancing Account will be made to reflect
differences between the actual purchased gas costs collected from customers and the
actual purchased gas costs incurred by the Company. Those differences are then
collected from or refunded to customers under Schedule 155 - Gas Rate Adjustment.
LP.U.C. No.27
Twentieth Revision Sheet 150
Replacing
Nineteenth Revision Sheet 150 150
lssued by
By
Avista Utilities
Kelly O. Norwood - Vice-President, State & Federal Regulation
l.P.U.C. No.27
Seventeenth Revision Sheet 155
Canceling
Sixteenth Revision Sheet 155
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 2.886d per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
3.O2OO per therm.
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued August 26,2015
lssued by Avista UtilitiesBy 7 .Kelly Norwood, Vice President, State & Federal Regulation*talaod
l.P.U.C. No.27
Seventeenth Revision Sheet 155
Canceling
Sixteenth Revision Sheet 155 155
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE.l55
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 2.8861 per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
MO Pertherm.
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued Auqust 26, 2015 Effective November 1. 2015
lssued by Avista UtilitiesBy Kelly Nonrood, Vice President, State & Federal Regulation
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - ]DAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 3=0566 per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0*P3l,, per therm.
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued Septemgerf:t:gl+Effective Nevemberl; 201,1
l.P.U.C. No.27
SDdeenth Revision Sheet 155
Canceling
Fifteenth Revision Sheet 155
lssued by Avista UtilitiesBy Kelly Norwood, Vice President, State & Federal Regulation
155
AVISTA UTILITIES
Case No. AVU-G-15-0 Y
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
August 26,2015
AVISTA UTILITIES
NOTICE OF IDAHO TARIFF CHANGE
(Natural Gas Service Only)
Notice is hereby given that the "Sheets" listed below of Tariff IPUC No. 27, covering natural gas service
applicable to Idaho customers of Avista Utilities have been filed with the Idaho Public Utilities Commission
(PUC) in Boise, Idaho.
Seventeenth Revision Sheet 155 updates the amortization rate used to refund or recover previous gas cost
differences and Twentieth Revision Sheet 150 updates the forward-looking cost of natural gas purchased for
customer usage.
These tariffs request an annual revenue decrease of approximately $10.3 million, or about l4.5yo. This filing
requests an effective date of November 1,2015.
PGAs are filed each year to balance the actual cost of wholesale natural gas purchased by Avista to serve
customers with the amount included in rates. This includes the natural gas commodity cost as well as the cost to
transport natural gas on interstate pipelines to Avista's local distribution system. If the request is approved,
Avista residential customers using an average of 6l therms a month could expect their bill to decrease by $7.94,
or 1 3.4 percent, for a revised monthly bill of $5 1 .28 beginning Nov. l , 20 1 5. Avista's natural gas revenues would
decrease by $10.3 million, or approximately 14.5 percent. The requested natural gas rate change by customer
segment is as follows:
Twenty-first Revision Sheet 150 canceling
Seventeenth Revision Sheet 155 canceling
General Service - Firm - Schedule 101 - Residential & Small Commercial
Large General Service - Firm - Schedules - Commercial111 & ll2
High Annual Load Factor Large - Interruptible Service Schedules 132
Twentieth Revision Sheet 150
Sixteenth Revision Sheet 155
-13.4o/o
-r8.0%
-24.6%
Avista does not mark up the cost of natural gas purchased to meet customer needs, so the filing does not increase
or decrease company earnings.
The Company's application is a proposal, subject to public review and a Commission decision. Copies of the
application are available for public review at the offices of both the Commission and Avista, and on the
Commission's homepage (www.puc.idaho.gov). Customers may file with the Commission written comments
related to the Company's filing. Customers may also subscribe to the Commission's RSS feed
(http://www.puc.idaho.gov/rssfeeds/rss.htm) to receive periodic updates via e-mail about the case. Copies of rate
filing are also available on our website, www.avistautilities.com/rates.
If you would like to submit comments on the proposed rate decrease, you can do so by going to the Commission
website or mailing comments to:
Idaho Public Utilities Commission
P. O. Box 83720
Boise, lD 83720-0074
Copies of the proposed tariff changes are also available for inspection in the Company's offices, its website
(www.avistautilities.com/rates), by calling [phone] or by writing:
Avista Utilities
Attention: Manager, Rates & Tariffs
P.O.Box3727
Spokane, W A. 99220-37 27
August 26,2015
AVISTA UTILITIES
Case No. AVU-G-15-0 >
EXHIBIT'OC"
Workpapers
August 26,2015
ritle Desenptioo Page Number
TARRIF CHANGE COMPARISONS
levenue Cha nee Summarv' !41 Change in Revenue as a result of filine 2
late Chanse Summarv' !A1 Chanse in rate, bv schedule, Schedule 150 and 155 3
PGA COMPONENT CATCUTATIONS
lnput!A1 Demand Volumes and Customers lnputs 4
lnout!A26 Commoditv lnDuts 5
Commodity!A1 Commodity WACOG Ca lculation 6
lnnut - Demend ContrartsrlA1 Demand WACOG Glculation 7
Amortization IA1 Amortization WACOG Calculation 9
OTHER
Conversion Factor'!A1 levenue Conversion Factor 10
GRI Fundins 3Rl Fundins 77
Lost and Unaccounted for Gas -ost and Unaccounted for Gas 72
Pioeline Tariff Sheets'!A1 [ranscanada - Alberta t3-22
ily'estcoast Enersv lnc.73-22
)ipeline Tariff Sheets - Foothills Pipeline Ltd.73-22
tlorthwest Pioeline Summarv t3-22
ily'estcoast Enerev lnc.t3-22
\,lorthwest Pipeline Summary 73-22
Tab: lndex
Avista t tilities
State of ldaho
Revenue Rate Change Sumamry
Based on 12 months November 1, 2015 - October 31, 2016
Schedule Therms
une
No.
Rate
Chanre
Revenue
lncr (Decrl
1 Schedule 150 PGA CommodiW
2 Rat Schcdule 101
3 R.tcschldule 111
4 Rste Schedul. 112
5 Ratrsch.dulcl3l
6 R3t. schedule 132
7
8
9 Schedule 150 PGA Demand
10 Ratc Schldul. 101
11 RatcSchcdule 111
12 Ratc Schedule 112
13 Rat schcdule 131
14 R.t! Srhcdulc 132
55,570,850 s
23,336,L67 50s0s
3s0,939 s
79,257,956
55,570,850 s
23,335,167 s0s0s
55,570,850 s
23,336,t57 s0s0s
350,939 s0s0s0s0s
(0.13312) j___11@I
(10,ss0,8191
55,570,850 s
23,336,L67 50so9
350,939 s
0
0
0
0
(0.13312) s
(0.133u) s
(0.133u) s
(0.13312) 5
0.00133 s
0.00133 s
0.00133 s
0.m170 s
0.m170 s-s
(o.ozoe7l s-s-s-9-9-s
(0.13mel s
(0.130(x)) s
(0.13179) s
(0.1s,r09) s
(0.13312) s
s
s
s
s
(7,397,5921
(3,106,s11)
74,rtz
3r,122
94,273
39,588
tzs,igst
:"
17,229,2071
(3,03s,801)
146,7L7l.
(26,69s)
:"
15
16
L7
18 Retc schedulc 1o1
19 Ratc Schedule l11
20 Rate schldulc u2
21 Ratc Schedule 131
22 Rat. schedule 132
23 customcrl
24 Customer2
25 customer3
25 Customcr4
27 Custom.rs
28
29
30 Total Change 150& 15s
31 Ratcschcdub 101
32 Rste schcdulc 111
33 Rat. schcdule u2
34 Ratcschedul. l3l
35 Retc schedulc 132
36 customer 1
37 customrr2
38 cBtomer3
39 Custom€r4
40 customers
4L
42
Total Chanre 79.257.956--
43 Rate Schedule 146 & Special Contracts
44
45 Total
46 %Changefrom Current Billed Revenue
S (6gszlS (10,344,531)
s
-
$ (10,344,6311
Present Billed
Prooosed Rates Revenue %Chanqe
schcdur€ 1o1 17,229,207l. s 54062000 -13
schedulc ul (3,035,801) S 15,903,m0 -r7
Schcdulc 112 0
sch.dule 131 0
schcdulr 132 (46,7171 5 190,000 -24
Refunds
T
Tab: Revenue Change Summary Paget 2 ol 22
Avista utilities
State of ldaho
Summary of Changes
1
2
3
4
5
6
7
8
9
10
11
L2
13
l4
15
L6
t7
18
19
20
27
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
4L
42
43
44
45
46
47
48
49
50
51
52
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
s0.10721 s0.38312
s0.10721 s0.38312
s0.10721 s0.38312
s0.383 12
s0.383 12
s0.108ss 50.2s072
s0.108ss so.zsozz
50.108ss 50.2s072
50.2s072
s0.00000 s0.2s072
s0.00134 (s0.13240) (50.131
s0.00134 (s0.13240) (50.131
s0.00134 (s0.13240) (s0.131
(s0.13240) (s0.132
50.00000 (50.13240) (50.132
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
GRF: 1.005016
s0.38s10
s0.38s10
s0.38s10
s0.38s10
s0.38510
1.(n5165
s0.2s198
s0.25198
s0.2s198
s0.2s198
s0.2s198
s0.00133 (s0.13312)
s0.00133 (s0.13312)
s0.00133 (50.13312)
(S0.13312)
s0.00000 (s0.13312)
(S0.131
(S0.131
(S0.1331
(S0.1331
Schedule 101
Schedule 111
Schedule 112
Schedule 131
Schedule 132
Proposed
Present
before revenue sensitive
before revenue sensitive
Change
before revenue sensitive
Schedule 101
Schedule 111
Schedule 112
Schedule 131
Schedule 132
Proposed
Schedule 101
schedule 111
Schedule 112
Schedule 131
Schedule 132
Schedule 101
schedule 111
Schedule 112
Schedule 131
Schedule 132
before revenue sensitive
Present
before revenue sensitive
Change
before revenue sensitive
Firm Sales
(Demand) (Commodity)
Amort Amort Total Amort Rate
(s0.02122) (50.00919) (so.o3o41
(50.02122) (So.oo919) (So.o3o41
(so.ooels) (So.o0s19
s0.00000
so.oo133 (s0.03004) (50.02871
so.oo133 (so.o30o4) (s0.02871
s0.022ss (s0.0208s)
so.o2zss (s0.o2o8s)
GRF: 1.005155
so.oo134 (so.o3o20)
so.oo134 (so.o3o20)
(5o.o3o2o)
50.02267 (So.o2o97) So.oouo
s0.02267 (s0.02097) so.oo17o
(s0.02097) (s0.0209
Tab: Rate Change Summary PaBe3 of 22
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Line
No.
AVISTA UTILITIES
Revenue Conversion Factor
Idaho - Natural Gas System
TWELVE MONTHS ENDED DECEMBER 31,2013
Descrintion Fector
Revenues
Expenses:
Uncollectibles
Commission Fees
Idaho State Income Tax
Total Expenses
Net Operating Income Before FIT
Federal Income Tax@35%
REVENUE COI.IVERS ION FACTOR
REVENUE GROSS UP:
I
)
3
4
5
6
7
8
1.000000
0.002608
0.002530
NA
0.994862
0.348202
0.646660
(l/1-.00s138)
Prior RCF
1.00s165
1.005016
Tab: RCF (Conversion Factor)
Page: L0of22
Avista Utilities
State of ldaho
Voluntary GRI Funding
Previous Pipeline Rate (PerTherm)
Current Pipeline Rate (PerTherm)
Reduction in Pipeline Funding Rate (Per Therm)
Monthly Rate (Daily Rate X 355 Dayslt2 Months)
NWP Demand Billing Determinants
Estimated Transportation Volumes (Therms)
GRI Funding Shortfall
ldaho Percentage
Total ldaho GRI Funding Shortfall
Northwest PipelineTF.1 TF.1
Reservation Volumetric
s0.00086 s0.00088
s0.00076 s0.0007s
Transcanada - GTN Pipeline Total
TF-1 TF-1
Reservation Volumetric
s0.00086 so.ooosa
so.ooozs s0.0007s
s0.00010 s0.00013
s0.00316
558,085,000
s0.00010 s0.00013
s0.00316
0
s1,764,000
30,0L%
So
30.57%
SoSo
30.01% 30.57%
S14.ooo s3,ooo sg,ooo s6,ooo s32,ooo
Set the GRI Funding at the 1UU99 Level.
Tab: GRI Page: 11 ot22
12 MOilTHS ET{DED TOTAL
LO38 & UTIACCOUT{TED FORGAS
BY DELIVERY POIilT. THERTS
IDAHO
lD SPO-CDA arca
ID LETI,IS.GLARK arc.
Bonnsl3
Genesee
Kellogg
toecow
Plnehud.Kngston
Sandpolnt
Smelbrllle'Page
IDAHO TOTAL
90,318,719 E9,7143n
DELIVERY
'tl],389.E28
RA'EilUE
43,940,658
#,771,Ul
LOSS +r-
129,272
177,0N
%oF
PURCHASE
0.97
0.39
2,il2,170
22l,2EO
t1,016,500
5,921,690
717,290
3,t10,010
111,U7,87e r
(1,096,223)
22,029
(200,864)
('o,388)
2n60,722
2,000,134
122,213
Lost and Uaccounted For Gas t2of 22
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Tab: Pipeline Tariff Sheets Pagei t5 of 22
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Page:Z?of22Tab: Pipeline Tariff Sheets
AVISTA UTILITIES
Case No. AVU-G-15-0L
E)GIIBIT'OD"
Pipeline Tariffs
August 26,2015
Northwest Pipeline LLC
FERC Gas Tariff
tr'ifth Revised Volume No.
Second Revised Sheet No. 16
Superseding
First Revised Sheet No. 16
1.
RATE SCHEDULE TF-1
Firm Transportation
AVAILABILlTY
This Rate Schedule is available as provided herein and
incorporates the General Terms and Conditions to any party (hereinafter
called "Shipper") for the transportation of natural gas by Transporter
through Transporterrs mainline transmisslon system under the following
conditions:
(a) Shipper desires firm service and Transporter has avallable
capacity to render such firm service for Shipper. If at the time
service is requested under thls Rate Schedule, Transporter doesnot have capacity to receive firm transportation gas at the
receipt point(s) requested for redefivery at the delivery
point(s) requested, Transporter shal1 offer to receive firm
transportation gas at other receipt point(s) where capacity may
be availabfe to enable redelivery at the delivery point (s)
requested;
(b) Transporter can commence the servj-ce contemplated without
need for construction of any additional pipeline fac11i-ti-es,
except facilities for which a facilities aqreement has been
entered into between Transporter and Shipper pursuant to Sectlon2l or 29 of the General- Terms and Conditions of this Tariff; and
(c) Shipper and Transporter have executed a Service Agreement
for service under thls Rate Schedufe.
As used in this Rate Schedule, Transporter's mainline
transmission system does not include Designated Laterals.
APPLICABIL]TY AND CHARACTER OF' SERV]CE
2.1 Applicability. This Rate Schedule sha11 apply to gas transported
by Transporter for Shlpper pursuant to the executed Service Agreementfor service under this Rate Schedule for TF-1 (Large Customer) and TF-1
(Smal-l Customer) service. The Service Agreement will specify the
customer category, i.e., whether the Shipper is a Large Customer or
Smal-I Customer and, 1f the Shipper is an j-ncremental expansion
customer, whether the Shipper is a Col-umbia Gorge Expansion customer, a
15-Year Evergreen Expansion customer or a 2S-Year Evergreen Expansj-on
customer.
2.
Page 1 of89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. 17
Superseding
First Revised Sheet No. 17
RATE SCHEDULE TE-1
Firm Transportation
(Continued)
2. APPLICABILITY AND CHARACTER OF SERVICE (Continued)
(a) TF-1 (Large Customer): AIl rate provisions contained in
this Rate Schedule apply to TF-l (Large Customers).
(b) TF-1 (Sma11 Customer): A TF-1 (Smal-I Customer) is anypipeline or dj-stribution company which elects Rate Schedule TF-1
(Sma11 Customer) service and whose aggregate Transportation
Contract Demand, as specifled in its Service Agreement(s)
hereunder, is for 10,000 Dth per day or less. (A Shipperqualified to elect either the TF-1 (Sma1l Customer) or TF-l-
(Large Customer) service hereunder may change its election
permanently only in connection with the filing of a general
Section 4 rate case by Transporter. Transporter shalI provJ-de
such Shippers with an opportunity to make such an election prior
to filing such rate appllcations. )
(c) Capacity Release Service is service initiated pursuant to
Section 22 of the General Terms and Conditions and an executed
Service Agreement for Rate Schedule TF-1 (Large Customer)
service.
(d) Any Rate Schedule TF-1 (Smal1 Customer) Shipper may convert
a1l- of its service temporarily to TF-1 (Large Customer) service
to participate in Transporter's Capacity Release Program without
amending its servj-ce agreement, provided that such temporary
conversion shaI1 be for a minimum term of twel-ve calendar months.Notice of the intent to so convert temporarily to TF-1 (Large
Customer) service must be given to Transporter electronically
usi-ng the TF-1 (Sma11 Customer) temporary conversion election
screen available in Northwest Passage on Transport.er's Designated
Site at least one (1) week prior to the beginning month for which
such conversion is to become effective. Shipper's temporary
conversion el-ection constitutes agreement to the temporary
conversion. Any TF-1 (Sma11 Customer) Shi-pper participating in a
temporary conversion to TF-1 (Large Customer) service shall payall rates and charges applicable to TE-1 (Large Customer) service
Page 2 of 89
Northwest Pipeline LLC
F'ERC Gas Tariff
Fifth Revised Yolume No. I
Second Revised Sheet No. 17-A
Superseding
First Revised Sheet No. 17-A
RATE SCHEDULE TF-1
Eirm Transportation
(Continued)
APPLICABILITY AND CHARACTER OF SERVICE (Continued)
2.1(d) (Continued)
during the term of such temporary conversion, including
reservation charges and surcharges applicable to such Shipper'sfu1l Transportation Contract Demand or such other rate to which
Transporter and Shi-pper mutually agree, reduced as applicable by
revenue credits appli-cable to Rel-eased Capacity. Any Rate
Schedule TF-1 (Sma11 Customer) Shipper which participates in such
a temporary converslon shal1 be entitled to return to Rate
Schedule TF-1 (Sma11 Customer) service upon expiration of the
term of the temporary conversj-on requested by such Shipper.
However, such Shipper shaI1 not be entitled to release its
capaclty rights for a term which extends beyond the term of the
temporary conversion.
2.2 Transportation Components. Transportation service under this Rate
Schedule, which does not include service on Designated Laterals, sha1lconsist of:
(a) The receipt by Transporter for the account of Shipper of
Shipper's gas at the Receipt Point(s) specified in the executed
Service Agreement;
(b) The transportation of such gas through Transporterrsplpeline system for the account of Shipper either directly or by
displacement; and
Page 3 of 89
Northwest Pipeline LLL
F'ERC Gas Tariff
F'ifth Revised Volume No. I
Second Revised Sheet No. 18
Superseding
First Revised Sheet No. 18
2.
RATE SCHEDULE TF-1
Firm Transportation (Contlnued)
APPLICABIL]TY AND CHARACTER OF SERV]CE (Continued)
(c) The delivery of gas in thermally equivalent quantities
after transportation (1ess any fuel use relmbursement furnishedin-kind i-n accordance with Section L4 of the General Terms and
Conditions) by Transporter to Shipper or for the account of
Shipper at the Delivery Point(s) specified in the executed
Service Agreement.
2.3 Character of Service. Transportation service rendered to Shipper
under this Rate Schedule is firm up to Shipper's Transportation Contract
Demand as speclfied in its executed Service Agreement, subject to the
executed Servi-ce Agreement and the limltations of this Rate Schedule,
and is not subject to curtailment or interruption except as expresslyprovided in the General Terms and Conditions. Transportation service
rendered under this Rate Schedule in excess of Shipper's Transportation
Contract Demand is not firm.
MONTHLY RATE(S)
Each month, Shipper will pay Transporter for service rendered
under this Rate Schedule the sum of the amounts specified in thisSection 3, as applicable. OnIy those rate provisions contained i-nSections 3.2, 3.4,3.5 and 3.7 apply to TF-1 (Sma11 Customers).
3.1 Reservation Charge.
(a) For TF-1 (Large Customer) service, the Reservation Chargeis the sum of the daily product of Shipper's Transportation
Contract Demand as specified 1n the executed Servlce Agreement
and the Base Tariff Reservation Charge stated on Sheet No. 5 ofthis Tariff that applies to the customer category ldentified inthe Service Agreement. Unless specifically adjusted pursuant to
Sectj-on 3.5 herein, the Maximum Base Tarlff Rate set forth on
Sheet No. 5 will- apply.
For capacity release service, the Reservation Charge is the
sum of the daily product of the accepted reservation charge bid
3.
Page 4 of 89
Northwest Pipeline LLC
FERC Ges Tariff
Fifth Revised Volume No.
Third Revised Sheet No. 18-A
Superseding
Second Revised Sheet No. 18-A
RATE SCHEDULE TF-1
Eirm Transportati-on
(Continued)
MONTHLY RATE(S) (Continued)
price which was bid by a Replacement Shipper or a Prearranged
Replacement Shlpper under the biddlng procedures for capacity
releases set forth in Section 22 of the General Terms and
Conditions and the Transportation Contract Demand acqulred by the
Replacement Shipper or the Prearranged Replacement Shipper.
3.2
(b) Shipper will pay the Reservation Charges commenci-nq wi-th the
primary term begin date set forth in the Service Agreement.
Volumetric Charge: The sum of (a) and (b) below:
(a) An amount obtained by multiplying (i) the quantity of Dth
schedufed for del-1very by Transporter to Shipper after
transportation during the month. after reduction for fuel use
reimbursement furnished in kind in accordance with the terms ofthe executed Service Agreement and Section 74 of the General
Terms and Conditions, by (i:-) the TF-1 (Large Customer) or TF-1
(Smal1 Customer) base tariff volumetric transportation rate asset forth on Sheet No. 5 of this Tariff. Unless specifically
adjusted pursuant to Section 3.5 herein, the Maximum Base Iariff
Rate set forth on Sheet No. 5 sha11 apply.
(b) An amount obtained by multiplying (i) the quantity of Dth
scheduled for deLivery by Transporter to Shipper aftertransportation during the month, after reduction for fuel- use
reimbursement furnished in kind in accordance with the terms of
the executed Service Agreement and Section 14 of the General
Terms and Conditions, by (ii) the ACA component as referenced 1nfootnote 2 on Sheet No. 5-A of this Tariff. This charge shaI1 be
subject to adjustment in accordance with Section 16 of the
General Terms and Conditions.
3.3 Volumetric Release Charges: For Capaclty Release service pursuant
to Section 22 of the General Terms and Conditions which is provided
under a volumetric bid rate the sum of (a), (b) and, if applicable, (c)
befow:
(a) The amount obtained by multiplyinq (i) the quantity of Dth
scheduled for delivery by Transporter to Replacement Shipper or
Prearranged Replacement Shipper after transportation during the
month, after
Page 5 of 89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Second Revised Sheet No. 19
Superseding
First Revised Sheet No. 19
RATE SCHEDULE TF-1
Firm Transportation
(Cont j-nued)
3. MONTHLY RATE(S) (Continued)
reduction for fuel use reimbursement furnished in kind in
accordance with the terms of the executed Service Agreement and
Section 14 of the General Terms and Conditions, by (ii) the
accepted vofumetric bid made by a Replacement Shipper or a
Prearranged Replacement Shipper and by (iii) the Rate Schedule
TE-1 Capacity Release Service Base Tariff Volumetric Charge, both
as set forth on Sheet No. 5 of this Tariff.
(b) The amount set forth in Section 3.2 (b) hereof.
(c) If the Releasing Shipper has specified a minimum average
load factor volumetric commitment, an amount equal to the accepted
volumetrj-c bid times the difference, if positive, between (i) thespecified average load factor times Replacement Shipper's or
Prearranged Replacement Shlpper's Transportation Contract Demand
times the number of days the Transportation Service Agreement isin effect during the month, and (ii) the quantity of Dth delivered
by Transporter to Replacement Shipper or Prearranged Replacement
Shipper under the subject Service Agreement during the month.
3.4 Additional Eacility Reservation Surcharge: A Shipper whocontracts for Columbia Gorge Expansion Project capacity will pay thefacility reservation surcharge set forth in the footnotes to Sheet No. 5of this Tariff and such surcharge wifl be 1n addition to all other
appllcable rates stated in this Section 3. The facility reservation
surcharge was derived based on Transportation Contract Demand and thecost of service attributable to the Columbla Gorge Expansion Project
incremental facilities and such derivation will remai-n in place until
such time as a different allocation procedure i-s specified by Commissionorder. The monthly facilities reservation surcharge will be the sum ofthe daily product of Shipper's Transportation Contract Demand asspecified in the executed Service Agreement and the applicable facilityreservatlon surcharge for the Columbia Gorge Expansion Projectfacilitj-es specified in the Footnotes to Sheet No. 5 of this Tariff.
Page 6 of 89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. 19-A
Superseding
First Revised Sheet No. 19-A
RATE SCHEDULE TF-1
Firm Transportation
(Continued)
3.MONTHLY RATE(S) (Continued)
3.5 Discounted Recourse Rates:
(a) Transporter reserves the right to discount at any ti-me the
Recourse Rates for any individual Shipper under any service
agreement wj-thout discounting any other Recourse Rates for that or
another Shipper; provided, however, that such discounted Recourse
Rates will- not be fess than the mi-nimum base rates set forth on
Sheet No. 5 of this Tariff, or any supersedlng tariff. Such
discounted Recourse Rates may apply to specific vol-umes of gas
(such as volumes above or below a certain level or aII volumes if
volumes exceed a certain leve1), volumes of gas transported during
speclfic time periods, and volumes of gas transported fromspecific receipt points and/or to specific delivery points, withinspecific corridors, or within other defined geographicaf areas.If Transporter discounts any Recourse Rates to any Shipper,
Transporter wiII file with the Commission any requlred reports
reflecting such discounts.
Page 7 of 89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Third Revised Sheet No.20
Superseding
Second Revised Sheet No.20
?
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
MONTHLY RATE (S) (Continued)
3.6 Charges for Capacity Release Service: The rates for capaclty
release service are set forth in Sheet No. 5. See Section 22 of Lhe
General Terms and Conditions for information about rates for capacity
rel-ease service, including information about acceptable bids. In the
event of a base tariff maximum and,/or minimum rate chanqe, wherein the
Replacement Shipper has not agreed to pay the Maximum Base Tariff Rate
or a percentage of the Maximum Base Tariff Rate (as it may change from
time-to-time), the Replacement Shipper wil-l- be obligated to pay:
(a) for capacj-ty release transactions that are subject to the
Maxj-mum Base Tariff Rate pursuant to FERC regulations: the lesserof the awarded bid rate and the new Maximum Base Tariff Rate
unless the awarded bid rate is less than the new minimum rate, in
which case the new minj-mum rate will apply for the remaining termof the release.
(b) for capacity release transactions that are not subject tothe Maximum Base Tarlff Rate pursuant to FERC regul-ations: thegreater of the mj-nimum base tariff rate and the awarded bld ratefor the remainlng term of the release.
3.7 Negotiated Rates: Notwithstanding the general provisions of this
Section 3, if Transporter and Shipper mutually agree to Negotiated
Rates for service hereunder, such Negotiated Rates will apply j-n lieuof the otherwise applicable rates identified in this Sectlon 3.
3.8 Facilities Charge: If Transporter and Shipper enter into afacllities aqreement pursuant to Section 21- or 29 of the General Terms
and Conditions for Transporter to construct facilities and for Shipperto pay a facilities charge, the facilitj-es charge will be set forth onExhibit C to an executed Service Agreement.
Page 8 of 89
Northwest Pipeline LLL
['ERC Gas Teriff First Revised Sheet No.20-A
l'ifth Revised Volume No. I Superseding
Substitute Originel Sheet No.20-A
RATE SCHEDULE TF-1
Firm Transportation
(Continued)
4. MINIMUM MONTHLY B]II
Unless Transporter and Shipper mutually agree otherwise, the Minimum
Monthly BiIl will consist of the Reservation Charge specified in
Sectj-on 3.1 of this Rate Schedule, as applicable.
5. TRANSPORTATION CONTRACT DEMAND
The Transportation Contract Demand is the maximum quantity of Gas,
expressed in Dth, that Transporter is obligated to receive (excl-usive
of fuel reimbursement furnished in-kind pursuant to Section 14 of the
General Terms and Conditions), transport and deliver for Shipper on a
Page 9 of 89
Northwest Pipeline LLL
FERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. 2l
Superseding
First Revised Sheet No.21
tr
RATE SCHEDULE TE-1
Firm Transportation (Continued)
TRANSPORTATION CONTRACT DEMAND (Continued)
firm basis on any one Gas Day, as specified in an executed Service
Agreement for service under this Rate Schedule. Transporter's servj-ce
obli-gation is limited to Shipper's Transportation Contract Demand as
adjusted for any released capacity pursuant to Section 22 of Lhe
General Terms and Condi-ti-ons.
As long as the Transportation Contract Demand, as adjusted for any
capacity releases, is not exceeded, Transporter sha11 be obllgated to
receive up to Shipperrs Maximum Daily Quantity (MDQ) at each Primary
Receipt Point and to defiver up to Transporterrs Maximum Daily Delivery
Obligation (MDDO) at each Primary Delivery Poj-nt at pressures at l-east
as great as the pressures specified in Shipperrs TF-1 Servj-ce
Agreement, on a firm basis, as such MDQ and MDDO are adjusted for any
rel-eased capacity pursuant to Sectj-on 22 of the General Terms and
Conditions.
The aggregate MDQ at the Primary Receipt Points, as specified j-n
a Service Agreement for service under this Rate Schedule, must equal
the Transportation Contract Demand. The aggregate MDDO at the Primary
Delivery Points, as specifj-ed in a Service Agreement for service underthis Rate Schedule, must equal the Transportation Contract Demand,
except for those Service Agreements that have aggregate MDDOs in excess
of Transportation Contract Demand as a result of the grandfathering ofpre-existing conjunctive nomination rights under the sales conversion
program approved in Docket No. CP92-79.
SCHEDULED OVERRUN TRANSPORTATION
On any day Shipper nominates quantities of gas in excess of
Shipper's Transportation Contract Demand specified in the executed
Service Agreement, Transporter wi-Il schedule such quantities in
accordance with the priority of service and curtailment policy
deli-neated 1n Section 12 of the General Terms and Conditi-ons.
6.
Page 10 of89
Northwest Pipeline LLC
FERC Gas Tarilf
Fifth Revised Volume No. 1
Second Revised Sheet No.21-A
Superseding
F'irst Revised Sheet No.21-A
RATE SCHEDULE TF-1
Firm Transportation (Continued)
6. SCHEDULED OVERRUN TRANSPORTATION (Continued)
For Schedufed Quantities i-n excess of Shipperrs Transportation
Contract Demand, Shipper shal1 pay for the excess gas transportation on
any such day the amounts specified beLow:
6.1 An amount obtained as the sum of (a) and (b):
(a) An amount obtained by multiplying (i) the quantity of Dth in
excess of Transportation Contract Demand by (ii) the maxlmum base
scheduled overrun transportation rate per Dth as set forth on
Sheet No. 5 of this Tariff, unless otherwise agreed to by Shipper
and Transporter.
(b) An amount obtained by multiplying (i) the quantity of Dth in
excess of Transportatlon Contract Demand by (ii1 the ACA
component as referenced in footnote 2 on Sheet No. 5-A of thisTariff. This charge sha1I be subject to adjustment in accordancewith Section 16 of the General Terms and Conditions.
(c) Additionally, if Shipper and Transporter have agreed to arate other than the maximum base scheduled overrun transportation
rate, Shipper may, when nominati-ng, electronically select an
option that will automatically increase (by a stated do11ar
increment per dth) such rate up to the rate that will increase
the likelihood of such quantities being scheduled pursuant to
Section L2 of the General Terms and Conditions.
6.2 The fuef reimbursement provided for in Section 7 of this Rate
Schedul-e.
Page 11 of89
Northwest Pipeline LLC
F'ERC Gas Tariff
Fifth Revised Volume No. I
First Revised Sheet No.22
Superseding
Substitute Original Sheet No.22
'7.
o
o
RATE SCHEDULE TF-1
Firm Transportati-on (Continued)
FUEL GAS REIMBURSEMENT AND BTU BALANCING
Refer to Sectlon 14 of the General Terms and Conditions.
SHIPPERIS ARRANGEMENTS PRIOR TO RECEIPT AND AFTER DELIVERY
Refer to Section 14 of the General Terms and Conditlons.
GENERAL TERMS AND CONDITIONS
The General Terms and Conditi-ons contained in this Tariff, except
as modlfied 1n the executed Service Agreement, are applicable to this
Rate Schedule and are hereby made a part hereof.
RESERVATION CHARGE ADJUSTMENTS
10.1 Eligibility. Any Shipper recej-ving firm transportation service
under this Rate Schedule may be eligible for reservation charge
adjustments if Transporter fails to provide primary firm transportati-on
due to scheduled or unscheduled maintenance, force majeure, or the
Unavaj-labi1ity of Transporter's Eacj-1ities.
1,0.2 Definitions. For purposes of this Section 10 onIy, the foJ-lowingdeflnitions apply:
Annual Deficiency Volume: The Annual Deficiency Volume for any
Constralnt Point is the sum of the Deficiency Volumes at that
Constraint Point for all Deflclency Periods during a cal-endar
year.
Annual Exemption Vofume: The Annual Exemption Volume for any
Constraint Point is the lesser of (1) the Constraint Point Design
Capacity or (2) the aggregate Constraint Point Firm Rights. times
365 (or 366 days for leap years), multiplied by three percent
(3? ) .
t0.
Page 12 of89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
First Revised Sheet No.22-A
Superseding
Substitute Originat Sheet No.22-A
10.
RATE SCHEDULE TF-1
Fj-rm Transportation (Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
Constraint Point: Any receipt point, delivery point, or corridor
through which primary nominations are not confirmed due to
scheduled or unscheduled maintenance, force majeure, or the
Unavailability of Transporter's Facilities at such constraintpoint or upstream or downstream of such point which reduce
Transporter's ability to flow gas through the point.
Constraint Poi-nt Actual Capacity: Physical capacity at a
Constraint Point which is available on any day.
Constraint Point Design Capacity: Physical desiqn capacj-ty at aConstraint Point when all facilities are fully functional under
reasonably representative operating assumptions.
Constraint Point Firm Rights: The rights of a Shipper under Rate
Schedule TE-1 to receive firm service throuqh a Constraint Poi-nt,
based on (1) primary receipt and delivery point rights and (2)corridor rights where prlmary receipt and,/or delivery points
establish a call on the relevant capacity.
Deficiency Period: A Deficiency Period begins on the day when
aggregate nominations usj-ng Constraint Point Firm Rights exceedConstraint Point Actual Capacity and Transporter is unable to
schedule otherwise acceptabfe nominations due to scheduled or
unscheduled maintenance, force majeure, or the Unavailability ofTransporter's Facil-ities. A Deficiency Period continues until theearlier of (1) the day when the Constraint Point Actual Capacityis restored to the 1evel of the Constraint Poi-nt Design Capacityor (2) the day when Transporter is able to schedule all otherwise
acceptable nomj-natlons with applicable Constraint Point FirmRights. A Deficiency Period may be a Declared Entitlement Period,
subject to the provisions of Section 14.6 of the General Terms and
Conditions.
Page '13 of 89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Third Revised Sheet No.22-B
Superseding
Second Revised Sheet No.22-B
10
RATE SCHEDULE TF-1
Firm Transportation (Continued)
RESERVATION CHARGE ADJUSTMENTS (Contlnued)
Deficiency Volume: The quantity derived from subtractlng the
Constraint Point Actual Capacity from the l-esser of (1) the
Constraint Point Design Capacity or (2) the aggregate Constraint
Point Firm Rights.
Excess Defj-ciency Volume: The Excess Deficiency Volume for any
Constraj-nt Point is the amount by which the Annual Deficiency
Volume for a Constraint Poj-nt exceeds the Annua1 Exemption Volume
for that Constraint Point.
Unavailability of Transporter's Facil-i-ties: Where Transporterf s
facilities that have been certificated, constructed, and placed
into service cannot be fully utlflzed for their intended operatj-on
and use for reasons other than scheduled or unscheduled
mai-ntenance or force majeure.
10.3 Determinatj-on of Adjustments. Pursuant to extensive negotiations
and the settlement reached between Transporter and Shippers as
identified in Docket No. RP99-81-000, and approved by the Commission on
November 6, L998,85 FERC $ 61,195, reservation adjustments will be
calculated as follows:
(a) On the first day of any Defi-ci-ency Period, Transporter will
post to its Designated Site the daily Deficiency Volume for the
affected Constraint Point, the Constralnt Point Design Capacity,
the Constraint Point Actual Capaclty, and the estimated duration
of the Deficiency Period. Such information may be revised as
applicable durlng the Deficiency Period.
(b) At least 24 hours prior to the end of any Deficiency
Period, Transporter will notify affected Shippers via a posting
on Transporter's Desiqnated Site, and, if specified by Shipper onthe Busi-ness Associate Information form, via an Internet E-mai1
or fax to the Shipper, of the date on whlch Transporter expects
to restore the Constraint Poj-nt Design Capacity or to be abl-e to
schedule all nominations with Constraint Point Firm Ri-ghts. If
Transporter j-s able to restore the Constraint Point Design
Capacity or is able to schedule such nominatj-ons, the Deficiency
Period will be deemed to have ended as specified by Transporter.
Otherwise, the Deficiency Period will continue until Constraj-nt
Point Design Capacity is restored or aggregate nominations with
Constrai-nt Point Firm Rights can be schedufed.
Page 14of89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
10.
First Revised Sheet No.22-C
Superseding
Substitute Original Sheet No. 22C
RATE SCHEDULE TE-1
Flrm Transportation (Continued)
RESERVAT]ON CHARGE AD.JUSTMENTS (CONtiNued)
(c) At the end of each calendar year, Transporter w111 post the
Annual Deficiency Volume and the Annual- Exemption Volume for each
affected Constraint Point. Transporter will then compare the
Annual Deficiency Volume for each affected Constraj-nt Point to
the Annual Exemption Volume for that Constraint Point. If thereis an Excess Deficiency Volume for any Constraint Point,
Transporter wiII al-l-ocate such Excess Defi-ciency Volume pro ratato the affected Shippers, based on Constraint Point Firm Rightsduring the Deficiency Period(s). Each Shipper's allocation will
be the sum of its applicable Constraint Polnt Firm Riqhts for all
Deficiency Periods divided by the sum of the applicable
Constraint Point Firm Rights of all Shippers for those Deficiency
Periods, multiplied by the Excess Deficiency Volume for a
Constraint Point.
(d) Transporter will calculate reservation charge adjustments
under each Service Agreement by multiplying a Shipper's allocated
share of the Excess Deficiency Volume for each Constraint Point
by the weighted averaqe Base Tariff Reservation Charge paid under
such Service Agreement for such Constraint Point for the
Deficiency Periods during which the Service Agreement was ineffect.
10.4 Payment. A11 reservatj-on charge adjustments will be issued orrefunds paid wlthin 90 days from the end of the applicable cafendar
year.
Page '15 of 89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
First Revised Sheet No.23
Superseding
Substitute Original Sheet No. 23
10
RATE SCHEDULE TF-1
Fj-rm Transportati-on
(Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
10.5 Sole Remedy. Reservation charge adjustments pursuant to this
Section 10 are Shipper's sole remedy for damages relating to
Transporter's faj-lure to provide primary firm transportation service
under Rate Schedule TE-1, unless such damages resuJ-t from the negligence
or wil-lful misconduct of Transporter.
RECEIPT AND DELIVERY PO]NT FLEX]BILITY
11.1 Permanent Changes to Prlmary Receipt and Delivery Polnts.
Subject to the availability provisions of this Rate Schedule, any
Shipper may permanently change primary receipt or delivery points by
amending Exhibit A of the Service Agreement.
11,.2 Use of Alternate Receipt and Delivery Points on a Temporary
Basis.
(a) A11 TF-1 Shippers may use any physical receipt or deliverypoint without amending Exhibit A of the Service Agreement. Suchpoints will be avallable for the receipt or delivery of gas on afirm basis, in accordance with the scheduling priorities
del-ineated in Section 12 of the General- Terms and Conditions.
(b) Transporter shall schedul-e service at alternate receipt anddelivery points on a daily basis pursuant to Section 14 of the
General Terms and Conditions.
(c) The scheduling of service at alternate receipt or deliverypolnts under a Service Agreement will not result in the loss of
firm contract rlghts to a Shipper's primary receipt or deliverypoints as specified in the Shipper's Servi-ce Agreement.
11.3 Procedures for Requesting Permanent Receipt and Delivery Point
Changes. Any Shipper who wishes to amend the pri-mary receipt ordelivery points, or the associated Maximum Daily Quantity or MaximumDaily Delivery Obligation named in Exhibit A of its Service Agreement,
wil-1 electronically request and execute on Transporter's Designated Site
an amendment to the applicable Service Agreement
11
Page 16of89
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
11.
Second Revised Sheet No. 24
Superseding
First Revised Sheet No.24
1,2
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
RECEIPT AND DELIVERY POINT FLEXIBILITY (Continued)
by 1:00 p.m. Central Clock Time (12:00 noon Mountain Cfock Time) four
(4) business days prior to the first of the month for which the change
is desired, or for changes to occur during a month, after the first of
the month, two (2) business days prior to the commencement of service,
unless otherwise agreed to by the parties. If Transporter determines
that a recelpt or del-ivery point change request can be honored, the
amendment to the Service Agreement will be executed by Transporter.
The change will become effective on the later of the requested
effective date or the date executed by Transporter, provi-ded that such
date shall not exceed fifteen days from the date of receipt of the
amendment by Transporter. Notice of the resulting changes in availabfe
receipt or delivery point capacity will- be posted to Transporter's
Designated Site at least one (1) business day prior to implementation
of such change.
Firm receipt and delivery point and associated mainline capacity will
be posted to Transporter's Designated Site pursuant to Section 25.2 ofthe General Terms and Conditions and wiff be availabl-e for permanent
receipt and/or delivery point changes only pursuant to the procedures
outlined in Section 25 of the General Terms and Conditions.
11,.4 Transporterrs Maximum Service Obligation. The total volumes
nominated for servj-ce on any day for all receipt or delivery points
must not exceed Transportation Contract Demand under a Shipper's firm
Service Agreement, except as otherwise provlded in Section 6 of this
Rate Schedule.
CONTRACT TERM EXTENSTONS
72.1, Standard Unilateral Evergreen Provision. If Transporter and
Shipper agree to i-nclude a standard unj-1atera1 evergreen provision asindicated on Exhibi-t A of a long-term Service Agreement, the following
conditions wilf apply:
(a)The established roffover period will be one year.
Page 17of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: March 25,2015
Effective: June 1,2015
PART 3
MAPS
v.4.0.0 Superseding v.3.0.0
The currently effective system map is available on GTN's Internet website at
http :l/tcplus.com/GTN/systemmap.
Docket No. P,}I 5-691 -000
Accepted: June 8,2015
Page 18 of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April 1l,20ll
Effective: April4, 201I
PART 4
STATEMENT OF RATES
v.2.0.0 Superseding v. I .0.0
STATEMENT OF RATES
Docket No. RPl 1-1986-000
Accepted: May 4,2011
Page 19 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
BASE
STF (e)
EXTENSION CHARGES
MEDFORD
E-r (D 0.003290 0.000000
E-2 (hXD 0.002972 0.000000
(Diamond 1)
E-2 (h)0) 0.001166 0.000000
(Diamond 2)
COYOTE SPRINGS
lssued: May29,2015
Effective: July 1,2015
PART 4.I
4.1 - Statement of Rates
FTS-I and LFS-I Rates
v. 12.0.0 Superseding v. 1 1.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-I and LFS-I
RESERVATIONDAILY DAILY
MILEAGE (a) NON-MILEAGE (b) DELIVERY (c) FLJEL (d)(Dth-MrLE) (Dth) (Dth-MILE) (Dth-MILE)
Max. Min. Max. Min. Max. Min. Max. Min.
0.000483 0.000000 0.038402 0.000000 0.000016 0.000016 0.0050% 0.0000%
(e) 0.000000 (e) 0.000000 0.000016 0.000016 0.00s0% 0.0000%
0.005498 0.000000 0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
E-3 (i)0.001412 0.000000 0.001420 0.000000 0.000000 0.000000
OVERRUN CHARGE C)
SURCHARGES
ACA (k)(k)(k)
Docket No. RPI 5-1028-000
Accepted: June 30,2015
Page 20 of 89
IIGas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: July25,2013
Effective: October l, 2013
PART 4.2
4.2 - Statement of Rates
ITS-l Rates
v.4.0.0 Superseding v.3.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS (a)
Rate Schedule ITS-l
MILEAGE (n) NON-MILEAGE (o) DELIVERY (c) FUEL (d)(Dth-Mile) (Dth) (Dth-Mile) (Dth-Mile)
Max. Min. Max. Min. Max. Min. Max. Min.
BASE (e) 0.000000 (e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-l (Medford) (f)
0.003290 0.000000 0.005498 0.000000 0.000026 0.000026
COYOTE SPRINGS
E-3 (Coyote Springs) (i)
0.001412 0.000000 0.001420 0.000000 0.000000 0.000000
SURCHARGES
ACA (k) (k) (k)
Docket No. RPl 3- l 1 00-000
Accepted: September 17, 2013
Page21 of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: May 29,2015
Effective: July 1,2015
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v.9.0.0 Superseding v.8.0.0
Docket No. RPl 5-l 028-000
Accepted: June 30,2015
Page 22 ol 89
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes:
(a) The mileage component shall be applied per pipeline mile to gas transported by GTN for
delivery to shipper based on the primary receipt and delivery points in Shipper's contract.
Consult GTN's system map in Section 3 for receipt and delivery point and milepost
designations.
(b) The non-mileage component is applied per Shipper's MDQ at Primary Point(s) of Delivery
on Mainline Facilities.
(c) The delivery rates are applied per pipeline mile to gas transported by GTN for delivery to
shipper based on distance of gas transported. Consult GTN's system map in Section 3 for
receipt and delivery point and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel, line loss, and other
utility purposes, plus other unaccounted-for gas used in the operation of GTN's combined
pipeline system in an amount equal to the sum of the current fuel and line loss percentage
and the fuel and line loss percentage surcharge in accordance with Section 6.38 of this
tariff, multiplied by the distance in pipeline miles transported from the receipt point to the
delivery point multiplied by the transportation quantities of gas received from Shipper
under these rate schedules. The current fuel and line loss percentage shall be adjusted each
month between the maximum rate of 0.0050% per Dth per pipeline mile and the minimum
rate of 0.0000% per Dth per mile. The fuel and line loss percentage surcharge is 0.0000%
per Dth per pipeline mile. No fuel use charges will be assessed for backhaul service.
Currently effective fuel charges may be found on GTN's Internet website under
"Informational Postings. "
(e) Seasonal recourse rates apply to short-term firm (STF) service under Rate Schedule FTS-I
(i.e., firm service that has a term of less than one year and that does not include multiple-
year seasonal service) and IT Service under Rate Schedule ITS-1. By March I of each year
GTN may designate up to four (4) months as peak months during a twelve-month period
beginning on June I of the same year through May 3l of the following year. All other
months will be considered off-peak months. Reservation rate components that apply to
STF service and per-unit-rate IT service are as follows (delivery charges and applicable
surcharges continue to apply):
4 Peak 3 Peak 2 Peak I Peak 0 PeakMos. Mos. Mos. Mo. Mos.
Peak NM Res. $0.053763 $0.053763 $0.053763 $0.053763 $0.038402
Peak Mi. Res. $0.000676 $0.000676 $0.000676 $0.000676 $0.000483
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: May 29,2015
Effective: July I ,2015
Off-PkNM Res. $0.030722 $0.033282
Off-Pk Mi. Res. $0.000387 $0.000419
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v.9.0.0 Superseding v.8.0.0
$0.03s330 s0.037006 $0.038402
$0.000444 $0.00046s $0.000483
Docket No. RP I 5-l 028-000
Accepted: June 30,2015
Page 23 of 89
(0
(e)
(h)
(i)
c)
Months currently designated as "Peak Months" may be found on GTN's Internet website
under "Informational Postings." By March I of each year, GTN will post the Peak Months
for the upcoming twelve-month period beginning June I of the same year.
Applicable to firm service on GTN's Medford Extension.
Reserved for Future Use.
Applies to Diamond Energy service, which commences 1998. Rate is negotiated
reservation charge of $0.002972 per Dth per day for first 45,000 Dth/d and $0.001166 per
Dth per day for the second 45,000 Dth/d. Revenues will be applied to annual revenue
requirement on the Medford Extension.
Applicable to firm service on GTN's Coyote Springs Extension.
The Ovemrn Charge shall be equal to the rates and charges set forth for intemrptible service
under Rate Schedule ITS-1.
(k) In accordance with Section 6.22 of the Transportation General Terms and Conditions of this
FERC Gas Tariff, Fourth Revised Volume No. 1-A, all Transportation services that involve
the physical movement of gas shall pay an ACA unit adjustment. The currently effective
ACA unit adjustment as published on the Commission's website (www.ferc.gw) is
incorporated herein by reference. This adjustment shall be in addition to the Base Tariff
Rate(s) specified above.
(D Daily reservation charges will be reset for leap years.
(m) Reserved.
(n) The Rate Schedule ITS-I Mileage Component shall be applied per pipeline mile to gas
transported by GTN based on the distance of gas transported. Consult GTN's system map
in Section 3 for receipt and delivery point and milepost designations.
(o) The Rate Schedule ITS-1 Non-Mileage Component shall be applied per Dth of gas
transported by GTN for immediate delivery to the facilities of another entity or an extension
facility.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: May26,20ll
Effective: June27,20ll
PART 4.4
4.4 - Statement of Rates
Reserved For Future Use
v.3.0.0 Superseding v.2.0.0
RESERVED FOR FUTI]RE USE
Docket No. RPI l-2132-000
Accepted: June 10,2011
Page 24 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: May 29,2015
Effective: July 1,2015
PART 4.5
4.5 - Statement of Rates
Parking and Lending Service
v.5.0.0 Superseding v.4.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS FOR
Parking and Lending Service
($/Dth)
BASE TARIFF RATE
MINIMUM MAXIMUM
0.2702681d0.0PAL Parking and Lending Service:
Notes:
Docket No. RPI 5-l 028-000
Accepted: June 30,2015
Page 25 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.6
4.6 - Statement of Rates
Negotiated Rate Agreements - FTS-I and LFS-I
v.3. 1.0 Superseding v.2.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULES FTS.I AND LFS.I
SHIPPER
Avista
Corporation /1
Coral Energy
Resources, LP /l
Pacific Gas and
Electric Co. /l
TERM OF RATE
CONTRACT SCHEDULE
tUUDt - FTS-I
10131/25
PRIMARY
RECEIPTDTH/D POINT
20,000 Medford
PRIMARY
DELIVERY RATEPOINT /213
Medford Ext. l7
Meter
Kingsgate ll004/1103 -
lt0
0U0U12
05l3Ut4
FTS-I 20,000 Malin
FTS-I 50,000 Kingsgate Malin l4
Issued: January 6,2012
Effective: January l, 2012
Docket No. RPl2-254-001
Accepted: January 30, 2012
Page 26 of 89
l
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-l and LFS-l
v.5.0.0 Superseding v.4. 1.0
lt
t2
t)
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Negotiated Rate Agreements Under Rate Schedules FTS-I and LFS-I
Explanatory Footnotes for Negotiated Rates
under Rate Schedules FTS-I and LFS-I
This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
Unless otherwise noted, all Shippers pay GTN's maximum Reservation Charge, Delivery
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
Index Price References: Unless otherwise noted, references to "Daily Index Price" shall
mean the price survey midpoint for the specified point as published in Gas Daily for the day
of gas flow. Weekend and holiday prices will be determined using the next available Gas
Daily publication. Unless otherwise noted, the references to the "NGI FOM" for a specified
point shall mean Natural Gas Intelligence's First of Month Bid Week Survey (Supplement
to NGI's Weekly Gas [ndex) Spot Gas Price for the specified point.
The Maximum LTF Settlement Rate, as filed on October 31,2007, in the Stipulation and
Agreement of Settlement in Docket No. RP06-407-000 ("Settlement"), and approved by the
Federal Energy Regulatory Commission on January 7,2008, applies to the remaining initial
term of contract F-I0526 beyond the "Moratorium," as that term is defined in Article V.A.l
of the Settlement.
l4
l5 Reserved
/6 Reserved
/7 The Reservation charge shall be
identified as FTS-l E-2 (WWP),
Period Percentage as shown in the
Effective Period
llly0t-10/31/02
rUv02-10131/03
tyll03-t013l/04
tUy04-10/31/0s
1yll05-10/31/06
rUll06-10/31/25
equal to the rate set forth
or its successor, multiplied
following table.
Percentage
7sYo
80%
85%
90%
95%
100%
in GTN's FERC Gas Tariff
by the appropriate Effective
Issued: July25,2013
Effective: October l, 2013
Docket No. RPl 3- l 100-000
Accepted: September 17,2013
Page 27 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-1 and LFS-1
v.5.0.0 Superseding v.4. 1.0
t9
lt0
The Daily Delivery Charge shall be equal to the 100% load factor equivalent of the FTS-I
E-2 rate, or its successor, and shall be multiplied by the positive difference between (a)
volumes delivered and (b) the contract MDQ times the appropriate Effective Period
Percentage.
Daily Delivery Charge : [Dth Delivered - (MDQ * Effective Period o/o)) * 100% Load
Factor Equivalent FTS-l E-2
18 Reserved
Reserved
The Reservation Rate shall be $0.02lDth applied to the MDQ ofthe Agreement. In addition
to the Reservation Rate, Coral shall pay commodity charges based on the actual gas
transported. The Commodity Rate shall be redetermined daily and will equal (the Gas
Daily Midpoint Price for PG&E, Malin minus the Gas Daily Midpoint Price for Stanfield,
Ore. minus an Allowance for GTN Fuel minus $0.004356/Dth minus $0.02lDth minus the
applicable ACA surcharge per Dth) multiplied by 50%.
The Allowance for GTN Fuel shall be determined daily by the following expression:
The Gas Daily Midpoint Price for Stanfield, Ore. multiplied by the applicable fuel and line
loss percentage for the actual path utilized to transport gas.
In the event that the index for Stanfield, Ore. and/or PG&E, Malin are not published on any
given day (other than a weekend or holiday), prices will be determined based on the last
published information for such index.
In the event that the index price for Stanfield, Ore. and/or PG&E, Malin are not published
on at least three business days within a span of six business days, either party may request
negotiation of a replacement rate structure (a "Renegotiation Request"). Upon such
Renegotiation Request, GTN and Coral will use diligent, good faith efforts to come to a
mutually agreeable replacement rate structure. Firm Transportation Service Agreement No.
08612 will terminate on the seventh day following a Renegotiation Request in the event the
parties do not agree on a replacement rate structure prior to such termination.
This Agreement shall become effective April l, 2003, and shall continue in full force and
effect through April 30, 2003 and month to month thereafter, with either party having the
right to terminate the Agreement, upon no less thanT days notice to the other, given prior to
the first day of any subsequent month.
Reservedltt
/12 Reserved
lssued: July25,2013
Effective: October l, 2013
Docket No. RP13-l 100-000
Accepted: September 17, 2013
Page 28 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
ll3 Reserved
ll4 Reserved
ll5 Reserved
116 Reserved
ll7 Reserved
/18 Reserved
Issued: July25,20l3
Effective: October l, 2013
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-I and LFS-I
v.5.0.0 Superseding v.4. 1.0
Docket No. RPI 3-l 100-000
Accepted: September 17, 2013
Page 29 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
SHIPPER
lssued: April24,2015
Effective: June 1,2015
PART 4.8
4.8 - Statement of Rates
Negotiated Rate Agreements - ITS-1 and PAL
v.5.0.0 Superseding v.4.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTI.ATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS-1 AND PAL
TERMOF RATE
CONTRACT SCHEDULE DTH/D
PRIMARY
DELIVERY RATEPOINT 12 /3
Docket No. RPI 5-905-000
Accepted: May29,2015
Page 30 of 89
PRIMARY
RECEIPT
POINT
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April24,2015
Effective: June 1,2015
PART 4.9
4.9 - Statement of Rates
Footnotes for Negotiated Rates - ITS-1 and PAL
v.5.0.0 Superseding v.4.0.0
DocketNo. RPl5-905-000
Accepted: May 29,2015
Page 31 of89
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATTON OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS-1 AND PAL
Explanatory Footnotes for Negotiated Rates under Rate Schedule ITS-l and PAL
ll This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
12 Unless otherwise noted, all Shippers pay GTN's maximum Mileage and Non-Mileage
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
/3 Index Price References: Unless otherwise noted, references to "Daily Index Price" shall
mean the price survey midpoint for the specified point as published in Gas Daily for the day
of gas flow. Weekend and holiday prices will be determined using the next available Gas
Daily publication. Unless otherwise noted, the references to the "NGI FOM" for a specified
point shall mean Natural Gas Intelligence's First of Month Bid Week Survey (Supplement
to NGI's Weekly Gas Index) Spot Gas Price for the specified point.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Cascade Natural Gas Corporation
Chewon USA Inc.
City of Burbank
IGI Resources, Inc.
Northern California Power Agency
Talisman Energy Inc
Paramount Resources US Inc.
Petro-Canada Hydrocarbons, Inc.
Sacramento Municipal Utility District
Avista Corporation
Avista Corporation
Cascade Natural Gas Corporation
Northwest Natural Gas Company
Puget Sound Energy, Inc.
Avista Corporation
Avista Corporation
Avista Corporation
Avista Corporation
Iberdrola Renewables, Inc.
Avista Corporation
Pacific Gas and Electric Company
Northwest Natural Gas Company
Petro-Canada Hydrocarbons, Inc.
Morgan Stanley Capital Group Inc.
Shell Energy North America (US), L.P.
BP Canada Energy Marketing Corp.
Sempra Energy Trading Corp.
EnCana Marketing (USA) Inc.
Nexen Marketing U.S.A., [nc.
Shell Energy North America (US), L.P.
Sierra Pacific Power Company
City of Glendale
Iberdrola Renewables, Inc.
Petro-Canada Hydrocarbons, Inc.
Chevron U.S.A. Inc.
Salmon Resources Ltd.
Constellation Energy Commodities
Group, Inc.
Enserco Energy Inc.
ConocoPhillips Company
UBS AG (London Branch)
Issued: October 1,2012
Effective: November l, 2012
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.3.0.0 Superseding v.2.1.0
NON-CONFORMING SERVICE AGREEMENTS
PURSUANT rO $ 154.1l2(b)
Contract Rate Effective Termination
Name of Shipper Number Schedule Date Date
152
153
154
r58
163
167
168
169
170
r77
178
179
180
181
182
2591
2857
2858
7828
8035
111
112
119
144
146
4621
4721
4770
6759
7047
7068
7804
7806
7807
7812
7816
8038
8176
8228
83 18
FTS-I
FTS-1
FTS-1
FTS-I
FTS-1
FTS-I
FTS.I
FTS-1
FTS-1
FTS.l
FTS.I
FTS-I
FTS-I
FTS-1
FTS-I
FTS-I
FTS-1
FTS-1
FTS-I
FTS-1
ITS-I
ITS-1
ITS-1
ITS-I
ITS-1
AIS-1
AIS-1
AIS-1
AIS-I
AIS-I
AIS-I
AIS-I
AIS-1
AIS-I
AIS-1
AIS-1
AIS-1
AIS-1
AIS-1
AIS-1
111U1993
r1nlt993
tUyt993
111111993
tt/U1993
lUU1993
tl!1993
1U111993
tuUt993
111111993
11/t/1993
t1/1lt993
tU1lt993
1U111993
1U111993
811lt99s
ty1lt99s
t1lUt995
61312001
lU112001
2lUt992
4lUt992
412211992
712311993
8/1t1993
12t111996
1lUt997
1t2s/1997
6n7n999
411012000
4t27t2000
sl301200t
st30/2001
sl30l200t
st30l200t
sl30l200t
81212001
1U2712001
U812002
41rU2002
1013U2023
1013y2023
10t3U2023
1013112013
1013U2023
10t3U2023
1013U2023
r0t3U2023
1013U2023
1013U2023
1013U2023
1013U2023
10t31t2023
1013112023
1013U2023
1013112025
1013112025
10t311202s
10t311202s
101311202s
1013U2010
3l3U20tt
4l22l20tt
913012010
81112010
1213U2010
1213112010
t2t3U20t0
12t3112010
1213U2010
12/4/2019
t2l3U202t
t2l3U202t
t2l3!2021
12131t2021
t2l3l202t
8t3112021
1113012021
U3112022
413012023
Docket No. RPI 3- I 03-000
Accepted: October 23, 2012
Page 32 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Concord Energy LLC
Tenaska Marketing Ventures
Cargill,Inc.
Merrill Lynch Commodities, Inc.
Apache Corporation
Tenaska Marketing Ventures
California Dept. of Water Resources
United Energy Trading, LLC
Select Natural Gas LLC
National Fuel Marketing Company LLC
Fortis Energy Marketing & Trading GP
Powerex Corp.
Louis Dreyfus Energy Services L.P.
Pacific Summit Energy LLC
Devlar Enerry Marketing LLC
Suncor Energy Marketing Inc.
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequent Enerry Management LP
Occidental Energy Marketing, Inc.
NextEra Enerry Power Marketing, LLC
Natural Gas Exchange, Inc.
Citigroup Enerry Inc.
IGI Resources, Inc.
Macquarie Cook Enerry, LLC
Sempra Energy Trading Corp.
EnCana Marketing (USA) Inc.
Shell Energy North America (US), L.P.
Husky Gas Marketing Inc.
Enserco Energy Inc.
National Fuel Marketing Company LLC
United States Gypsum Company
Northwest Natural Gas Company
Chevron U.S.A. Inc.
San Diego Gas & Electric Company
Southern California Gas Company
Puget Sound Energy, Inc.
Hermiston Generating Company, L.P.
City of Glendale
Iberdrola Renewables, Inc.
Questar Energy Trading Company
El Paso Energy Marketing Company
Sempra Energy Trading Corp.
Constellation Energy Commodities
Group, Inc.
ConocoPhillips Company
Tractebel Energy Marketing Inc.
UBS AG (London Branch)
Issued: October 1,2012
Effective: November l, 2012
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.3.0.0 Superseding v.2.1.0
8421
8559
8594
8674
8670
8880
8887
9002
8978
9035
9l t5
9149
9281
9285
9630
9774
10197
10308
10336
10359
10625
10639
10646
4576
4619
4720
4868
4908
s348
5677
5679
s837
5992
6226
6378
6613
7061
7798
7803
7805
7819
7820
7833
8037
8229
8283
83 16
AIS-I
AIS-1
AIS.I
AIS-I
AIS.I
AIS-I
AIS-I
AIS-I
AIS.I
AIS-1
AIS-1
AIS-I
AIS-1
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-1
AIS-I
AIS-I
AIS-1
AIS-I
PS-1
PS-1
PS-I
PS.1
PS-1
PS-I
PS-I
PS-1
PS-I
PS-1
PS-1
PS.I
PS-1
PS-1
PS-1
PS.1
PS-1
PS-1
PS-I
PS-1
PS-I
PS-I
PS.I
PS-1
713u2012
t213U20t2
313l/2013
6n3t2023
613012013
r113012013
7lt/2011
2t2812014
31312014
413012014
6t3012014
713U2014
t0/3u2014
t0l3U20t0
5l3U20ts
9130/201s
7l25l20tt
t013y20tt
r013112010
r2l3t/2010
413012018
413012018
513112018
1213U2010
t2l3U20t0
t213u20t0
t2l3y20t0
t2l3y20t0
1213u2010
t2l3u20t0
t2/3112010
5/1712010
1213y2023
t2l3U20t0
t213u20t0
t2/3,/2010
412012020
t2l3y202t
1213y2021
t2l3U202r
t2l3u202t
t2l3t/2021
618/2020
813y2021
l/3112022
313U2022
413012023
7t2212002
t/1t2003
311912003
611312003
71U2003
121U2003
121u2003
31U2004
31312004
412712004
71r712004
8n6t2004
111812004
1U1512004
6nt2005
101U2005
7126/2006
1012712006
tUt/2006
1212212006
4lt0/2008
4/29/2008
st30/2008
t2lUt996
tzlt/1996ylt997
3/U1997
3|s11997
7t3t1997
r0l6lt997
t0/7/1997
tt/311997
2/1311998
slt4lt998
8/25/t998
t2/1411998
412012000
st301200t
sl30/2001
s/3012001
s/3012001
5/3012001
6/1412001
8/212001
U812002
3/1412002
4/1112002
Docket No. RPI 3-l 03-000
Accepted: October 23, 2012
Page 33 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No, 1-A
Issued: October 1,2012
Effective: November l, 2012
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.3.0.0 Superseding v.2.1.0
RWE Trading Americas Inc.
Fortis Energy Marketing & Trading GP
Concord Energy LLC
Select Natural Gas LLC
Tenaska Marketing Ventures
Cargill, Inc.
United Energy Trading, LLC
Apache Corporation
Occidental Energy Marketing, Inc.
Tenaska Marketing Ventures
California Dept. of Water Resources
Devon Canada Marketing Corporation
Merrill Lynch Commodities, Inc.
Pacific Summit Energy LLC
Louis Dreyfus Energy Canada LP
Louis Dreyfus Energy Services L.P.
Devlar Enerry Marketing, LLC
Suncor Energy Marketing Inc.
J.P. Morgan Ventures Enerry Corporation
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequent Enerry Management LP
El Paso Ruby Holding Company, LLC
8324
8340
8406
8534
8539
8595
8652
8668
8784
8873
8886
8923
9018
9173
9263
9273
9s84
9772
9948
10r95
10310
10332
12071
PS-1
PS.I
PS.I
PS-I
PS.I
PS-I
PS-I
PS-1
PS-I
PS-I
PS-I
PS-1
PS-1
PS.1
PS-I
PS-I
PS-I
PS-I
PS-I
PS-I
PS-I
PS.I
FTS-1
411612002
512/2002
712212002
1111512002
121y2002
311912003
s12312003
71y2003
911012003
tzn/2003
12nt2003
21y2004
4t7/2004
8130/2004
1012912004
1U4t2004
512/2005
101112005
2lt/2006
712612006
10127/2006
tUU2006
tyU20t2
413012022
513U2022
713U2012
t013U20t2
113012012
313U20t3
s13U2013
6/30/2013
813U2013
tU30t20t3
7/U20tt
t/3U2014
4/7t2014
8/30/2010
t0t3U20t0
r0/3U2014
4/3012015
913012015
U3l20r6
7l25l20tt
t013U20tt
t013u20tt
3l3t/2018
Docket No. RPI 3- I 03-000
Accepted: October 23, 2012
Page 34 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April24,2015
Effective: June 1,2015
PART 5
RATE SCHEDULES
v.3.0.0 Superseding v.2.0.0
RATE SCHEDULES
Firm Transportation Service (FTS-l)
Limited Firm Transportation Service (LFS-1)
Intemrptible Transportation Service (ITS- I )
Unbundled Sales Service (USS-l)
Parking and Lending Service (PAL)
Docket No. RP I 5-905-000
Accepted: May 29,2015
Page 35 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April ll,20ll
Effective: April 4, 201I
PART 5.I
5.1 - Rate Schedules
Rate Schedule FTS-l - Firm Transportation Service
v.2.0.0 Superseding v. I .0.0
RATE SCHEDI.JLE FTS.I
FIRM TRANSPORTATION SERVICE
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 36 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April I l,20ll
Effective: April4, 201I
PART 5.I.1
5.1.1 - Rate Sched FTS-I
Availability
v.2.0.0 Superseding v. 1.0.0
5.1.1 AVAILABILITY
This rate schedule is available to any party (hereinafter called "Shipper") quali$ing for
service pursuant to the Commission's Regulations contained in l8 CFR Part 284, and who
has executed a Firm Transportation Service Agreement with GTN in the form contained
in this FERC Gas Tariff, Fourth Revised Volume No. l-A.
Docket No. RPI I -l 986-000
Accepted: May 4,2011
Page 37 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I1,2011
Effective: April4, 2011
5.1.2 APPLICABILITY AND CHARACTER OF SERVTCE
This rate schedule shall apply to ftrm gas transportation services performed by GTN for
Shipper pursuant to the executed Firm Transportation Service Agreement between GTN
and Shipper. GTN shall receive from Shipper such daily quantities of gas up to the
Shipper's Maximum Daily Quantity as specified in the executed Firm Transportation
Service Agreement between GTN and Shipper plus the required quantity of gas for fuel
and line loss associated with service under this Rate Schedule FTS-I and redeliver an
amount equal to the quantity received less the required quantity of gas for fuel and line
loss. This transportation service shall be frm and not subject to curtailment or
intemrption except as provided in the Transportation General Terms and Conditions. A
Shipper's Maximum Daily Quantity shall be a uniform quantity throughout the contract
term, except that GTN may, on a not unduly discriminatory basis, agree to differing
monthly levels in the Shipper's Maximum Daily Quantity during the term of Shipper's
contract. Shipper's Maximum Daily Quantity and any differing levels in the Maximum
Daily Quantity, as well as the period of such differing Maximum Daily Quantity levels,
shall be specified in the executed Firm Transportation Service Agreement.
Firm transportation service shall be subject to all provisions of the executed Firm
Transportation Service Agreement between GTN and Shipper and the applicable
Transportation General Terms and Conditions.
PART 5.I.2
5 .l .2 - Rate Sched FTS- I
Applicability and Character of Service
v.2.0.0 Superseding v. 1.0.0
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 38 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: May 26,2011
Effective: June 27, 2011
PART 5.I.3
5.1.3 - Rate Sched FTS-l
Rates
v.3.0.0 Superseding v.2.0.0
5.I.3 RATES
Shipper shall pay GTN each month the sum of the Reservation Charges, the Delivery
Charge, plus any applicable Extension Charge, Overrun Charge and applicable surcharges
for the quantities of natural gas delivered. The rate(s) set forth in GTN's current Effective
Rates and Charges for Transportation of Natural Gas in this FERC Gas Tariff, Fourth
Revised Volume No. l-A are applied to transportation service rendered under this rate
schedule.
Docket No. RPI l-2132-000
Accepted: June 10, 201 I
Page 39 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: I|u4ay26,20ll
Effective: June 27,2011
PART 5.1.3.1
5.1.3.1- Rate Sched FTS-l
Reservation Charge
v.3.0.0 Superseding v.2.0.0
5.1.3.1 Reservation Charge.
The Reservation Charge shall be the sum of the Mileage and the Non-Mileage
Component:
(a) Mileage Component.
The Mileage Component shall be the product of the currently effective
Mileage Rate as set forth in Section 4.1, the distance, in pipeline miles,
from the Primary Point(s) of receipt to the Primary Point(s) of Delivery on
Mainline Facilities as set forth in Shipper's Contract, and the Shipper's
Maximum Daily Quantity at such Point(s).
(b) Non-MileageComponent.
The Non-Mileage Component shall be the product of the currently
effective Non-Mileage Rate as set forth in Section 4.1 and the Shipper's
Maximum Daily Quantity at Primary Point(s) of Delivery on Mainline
Facilities.
(c) Shipper's obligation to pay the Reservation Charge is independent of
Shipper's ability to obtain export authorization from the National Energy
Board of Canada, Canadian provincial removal authority, and/or import
authorization from the United States Department of Energy, and shall
begin with the execution of the Firm Transportation Service Agreement by
both parties. The Reservation Charge due and payable shall be computed
beginning in the month in which service is first available (prorated if
beginning in the month in which service is available on a date other than
the first day of the month). Thereafter, the daily Reservation Charge shall
be due and payable each month during the Initial (and Subsequent) Term(s)
of the Shipper's executed Firm Transportation Service Agreement and is
unaffected by the quantity of gas transported by GTN to Shipper's delivery
point(s) in any month except as provided for in Sections 5.1.3.9 and
5.1.3.10 ofthis rate schedule.
Docket No. RP 1 | -2132-000
Accepted: June 10, 201 1
Page 40 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April lI,20ll
Effective: April4, 2011
PART 5.1.3.2
5 .l .3.2- Rate Sched FTS- I
Delivery Charge
v.2.0.0 Superseding v. 1.0.0
5.1.3.2 Delivery Charge.
The Delivery Charge shall be the product of the Delivery Rate as set forth in
Section 4.1, the quantities of gas delivered in the month (in Dth) (excluding
Authorized Overrun) at point(s) of delivery on Mainline Facilities, and the
distance, in pipeline miles, from the point(s) of receip to point(s) of delivery on
Mainline Facilities.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page41 of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April 1l,20ll
Effective: April4, 2011
PART 5.1.3.3
5.1.3.3- Rate Sched FTS-1
Extension Charge
v.2.0.0 Superseding v. 1.0.0
5.1.3.3 Extension Charge.
If Shipper designates a Primary Point of delivery on an Extension Facility, then
in addition to all other charges that are applicable, Shipper shall pay the
Extension Charge, which shall consist of a reservation and delivery component.
(a) The reservation component of the Extension Charge shall be the product of
Shipper's Maximum Daily Quantity at the Primary Point(s) of delivery on
the Extension Facility, the applicable Extension reservation rate as set forth
in Section 4.1, and the distance, in pipeline miles, from the Receipt
Point(s) on the Extension Facility to the Primary Point(s) of delivery.
(b) The delivery component of the Extension Surcharge shall be the product of
the quantities delivered at the point(s) of delivery on the Extension
Facility, the applicable Extension delivery rate as set forth in Section 4.1,
and the distance, in pipeline miles, from the Receipt Point(s) on the
Extension Facility to the point(s) of delivery.
Docket No. RPI I -1986-000
Accepted: May 4,2011
Page 42 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
lssued: April ll,20ll
Effective: April4, 201I
PART 5.1.3.4
5.1.3.4- Rate Sched FTS-I
Authorized Ovemrn Charge
v.2.0.0 Superseding v. 1.0.0
5.1.3.4 Authorized Ovemrn Charge.
Quantities in excess of Shipper's MDQ shall be transported when capacity is
available on the GTN system and when the provision of such Authorized
Ovemrns shall not affect any Shipper's rights on the GTN System. Authorized
Ovemrns are intemrptible in nature. The rate charged shall be the same as the
rates and charges for intemrptible transportation under Rate Schedule [TS-l as
set forth in Section 4.1, and such Authorized Ovemrns shall be subject to the
priority of service provisions of Section 6.19 of the Transportation General
Terms and Conditions.
Docket No. RPI l-l 986-000
Accepted: I&'f.ay 4,2011
Page 43 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April 1l,20ll
Effective: April 4, 201I
PART 5.1.3.5
5.1.3.5- Rate Sched FTS-I
Applicability of Surcharges
v.2.0.0 Superseding v. 1.0.0
5.1.3.5 Applicability of Surcharges.
Shipper shall pay all reservation and usage surcharges applicable to the service
provided to such Shipper as set forth in GTN's FERC Gas Tariff, Fourth
Revised Volume No. l-A. Such surcharges shall be deemed to be part of
Shipper's Reservation and Delivery Charges.
Docket No. RPl l-1986-000
Accepted: INday 4,2011
Page 44 of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: August 1,2014
Effective: September l, 2014
PART 5.1.3.6
5.1.3.6- Rate Sched FTS-I
Discounts
v.3.0.0 Superseding v.2.0.0
5.1.3.6 Discounts.
Shipper shall pay the Maximum Reservation Charge, and the Maximum
Delivery Charge for service under this Rate Schedule unless GTN offers to
discount the Mileage Rate components or the Non-Mileage Rate components of
the Reservation Rate or the Delivery Rate under this rate schedule. If GTN
elects to discount any such rate, GTN shall provide notice to Shipper of the
effective date of such discount and the quantity of gas so affected; provided,
however, such discount shall not be unduly discriminatory between individual
shippers. The rates for service under this rate schedule shall not be discounted
below the Minimum Reservation Charge, the Minimum Delivery Rate, and
applicable ACA Surcharge.
Docket No. RP14-l I 54-000
Accepted: August 27, 2014
Page 45 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No.
5.1.3.7 Backhauls.
Backhauls (as defined in Section 6.1 paragraph 3l of the Transportation General
Terms and Conditions) shall be subject to the same charges as forward haul (as
defined in Section 6.1 paragraph 30 of the Transportation General Terms and
Conditions) except that no gas shall be retained by GTN for compressor station
fuel, line loss and other unaccounted-for gas. Backhauls are subject to the
operating conditions of GTN's pipeline and will not be made available to
Shipper if GTN determines, in its sole discretion, that such transportation is
operationally infeasible or otherwise not available.
PART 5.1.3.7
5.1.3.7- Rate Sched FTS-I
Backhauls
v.2.0.0 Superseding v. 1.0.0
Issued: April 1I,20ll
Effective: April4, 201I
Docket No. RPI l-1986-000
Accepted: N{.ay 4,2011
Page 46 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: May 1,2015
Effective: June l, 2015
PART 5.1.3.8
5.1.3.8- Rate Sched FTS-I
Capacity Release
v.3.0.0 Superseding v.2.0.0
5.1.3.8 Capacity Release.
(a) ReleasingShippers:
Shipper shall have the option to release capacity pursuant to the provisions
of GTN's capacity release program as specified in the Transportation
General Terms and Conditions. Shipper may release its capacity, up to
Shipper's Maximum Daily Quantity under this rate schedule, in accordance
with the provisions of Section 6.28 of GTN's Transportation General
Terms and Conditions of this FERC Gas Tariff, Fourth Revised Volume
No. l-A. Shipper shall pay a fee associated with the marketing of capacity
by GTN (if applicable) in accordance with Section 6.28 of the
Transportation General Terms and Conditions. This fee shall be negotiated
between GTN and the Releasing Shipper.
(b) ReplacementShippers:
Shipper may receive released capacity service under this rate schedule
pursuant to Section 6.28 of the Transportation General Terms and
Conditions and is required to execute a service agreement in the form
contained for capacity release under Rate Schedule FTS-I in this Fourth
Revised Volume No. 1-A.
Shipper shall pay GTN each month for transportation service under this
rate schedule and as set forth in GTN's current Statement of Effective
Rates and Charges in this Fourth Revised Volume No. I -A. Charges to be
paid shall be the sum of the Reservation Charge, Delivery Charge, and
other applicable surcharges or penalties.
Docket No. RP I 5-955-000
Accepted: May 20,2015
Page 47 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: December 6, 2012
Effective: January 12, 2012
PART 5.1.3.9
5.1.3.9- Rate Sched FTS-I
Reservation Charge Credit - Force Majeure Event
v.5. 1.0 Superseding v.3.0.0
Docket No. RPl2-15-005
Accepted: January 16, 2013
Page 48 of 89
5.1.3.9 Reservation Charge Credit - Force Majeure Event.
As used in this Section 5.1.3.9, Firm Daily Volume shall mean the volume of
gas which GTN is obligated to deliver on a firm basis at Shipper's primary firm
delivery point(s) on a Gas Day, based on confirmable nominations for firm
service within Shipper's Maximum Daily Quantity. If due to an event of Force
Majeure as defined in Section 6.10 of the General Terms and Conditions of this
FERC Gas Tariff, GTN is unable to deliver any portion of Shipper's Firm Daily
Volume for a period greater than ten (10) consecutive days, then for each day
beyond ten (10) days that GTN so fails to provide service the applicable
reservation charges including applicable reservation-based surcharges shall not
apply to the quantity of gas not delivered by GTN within the Shipper's Firm
Daily Volume; provided, however, that these charges shall not be eliminated to
the extent that the Shipper utilizes secondary point service.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: December 6, 2012
Effective: January 12, 2012
PART 5.1.3.10
5. 1.3. I O-Rate Sched FTS- I
Reservation Chg. Credit - Non-Force Majeure Event
v.5. 1.0 Superseding v.3.0.0
Docket No. RPl2-15-005
Accepted: January 16, 2013
Page 49 of 89
5.1.3.10 Reservation Charge Credit - Non-Force Majeure Event.
As used in this Section 5.1.3.10, Firm Daily Volume shall mean the volume of
gas which GTN is obligated to deliver on a frm basis at Shipper's firm delivery
point(s) on a Gas Day, based on confirmable nominations for primary firm
service within Shipper's Maximum Daily Quantity. Except as provided for in
Section 5.1.3.9 above, in the event GTN fails to deliver any portion of Shipper's
Firm Daily Volume on any Gas Day under any firm contract, then the applicable
reservation charges including applicable reservation-based surcharges shall not
apply to the quantity of gas not delivered by GTN within the Shipper's Firm
Daily Volume; provided, however, that these charges shall not be eliminated to
the extent that the Shipper utilizes secondary point service.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: December 6, 2012
Effective: January 12, 2012
PART 5.1.3.11
5.1 .3.1 l -Rate Sched FTS- I
Reservation Charge Credit - Confirmable Nominations
v.3.0.0 Superseding v.2.0.0
Docket No. Ml2-15-005
Accepted: January 16, 2013
Page 50 of 89
5.1.3.1 I Reservation Charge Credit - Confirmable Nominations.
Any exemption from crediting for nominated amounts not confirmed, as
provided in Sections 5.1.3.9 and 5.1.3.10 hereof is limited to events caused
solely by the conduct of others, such as Shipper or upstream or downstream
facility operators not controlled by GTN.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: August 1,2014
Effective: September l, 2014
PART 5.1.3.12
5.1.3.12-Rate Sched FTS-I
Negotiated Rates
v. 1.0.0 Superseding v.0.0.0
5.1.3.12 Negotiated Rates.
Notwithstanding any provision of GTN's Tariff to the contrary, GTN and
Shipper may mutually agree in writing to a Negotiated Rate (including a
Negotiated Rate Formula) with respect to the rates, rate components, charges, or
credits that are otherwise prescribed, required, established, or imposed by this
Rate Schedule or by any other applicable provision of GTN's Tariff.
Docket No. RPl4-1 I 54-000
Acceped: August 27, 2014
Page 51 of89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April 1l,20ll
Effective: April4, 201I
PART 5.1.4
5.1.4 - Rate Sched FTS-I
Fuel and Line Loss
v.2.0.0 Superseding v. 1.0.0
5.1.4 FI.JEL A}ID LTNE LOSS
For all Forward Hauls, Shipper shall furnish to GTN quantities of gas for compressor
station fuel, line loss and other utility purposes, plus other unaccounted for gas used in the
operation of GTN's combined pipeline system between the International Boundary near
Kingsgate, British Columbia and the Oregon-California boundary for the transportation
quantities of gas delivered by GTN to Shipper, based upon the effective fuel and line loss
percentages in accordance with Section 6.38 of the General Terms and Conditions. No
fuel charge shall apply to transactions that do not involve a forward haul movement of
gas.
Docket No. RPl l-1986-000
Accepted: May 4,2011
Page 52 of 89
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April 1l,20ll
Effective: April4,2Dll
5.I.5 TRA}.ISPORTATION GENERAL TERMS AND CONDITIONS
All of the Transportation General Terms and Conditions are applicable to this rate
schedule, unless otherwise stated in the executed Firm Transportation Service Agreement
between GTN and Shipper. Any future modifications, additions or deletions to said
Transportation General Terms and Conditions, unless otherwise provided, are applicable
to firm transportation service rendered under this rate schedule, and by this reference, are
made a part hereof.
PART 5.I.5
5.1.5 - Rate Sched FTS-l
Transportation General Terms and Conditions
v.2.0.0 Superseding v. 1.0.0
Docket No. RPI 1-1986-000
Accepted: May 4,2011
Page 53 of 89
F'oothills Pipe Lines Ltd.
Page 1
Rate Schedule FT
RATE SCHEDULE FT
FIRM TRANSPORTATION SERYICE
1. AVAILABILITY
This Rate Schedule FT, Firm Transportation Service is available to any Shipper which
has:
(a) Satisfied all applicable requirements as set forth in the Capacity Allocation
Procedures and subsection 5.8 of the General Terms and Conditions of this Gas
Transportation Tariff; and
Executed a Service Agreement, Firm Transportation Service with Company, for a
minimum term of one (l) year ending on the last day of a Month.
For Zones 8 and 9 only, Backhaul service is also available under Rate Schedule FT, Firm
Transportation Service.
2. APPLICABILITY
This Rate Schedule FT, Firm Transportation Service shall apply to all transportation
services under Shipper's Service Agreement, Firm Transportation Service other than
service specifically provided for in another rate schedule, as of the Billing
Commencement Date, whether or not gas is actually transported.
3. SERYICE DESCRIPTION
Service rendered by Company for Shipper under this Rate Schedule FT, Firm
Transportation Service consists of:
(a) The receipt of gas from Shipper (or for Shipper's account) at each Receipt Point
as specified in the Service Agreement, Firm Transportation Service;
Effective Date: April l, 2007
Page 54 of 89
(b)
TARIFF_PHASE I
Foothills Pipe Lines Ltd.
Page2
Rate Schedule FT
(c)
The transportation of gas by Company through the transportation system,
described in section 6 hereof; and
The delivery by Company to Shipper of gas nominated by Shipper (or for
Shipper's account) at each Delivery Point specified in the Service Agreement,
F irm Transportation Service.
4. SERVICE AGREEMENT
This Rate Schedule FT, Firm Transportation Service is subject to all terms, conditions,
stipulations and provisions of the Service Agreement, Firm Transportation Service.
5. GENERAL TERMS AI\iD CONDITIONS
This Rate Schedule FT, Firm Transportation Service is subject to all terms, conditions,
stipulations and provisions of the General Terms and Conditions of this Gas
Transportation Tariff.
SUBSIDIARY COMPANIES AI\D ZONES
General
Company's transportation system consists of operating segments with each segment
operated by a Subsidiary Company. Company and Subsidiary Companies have entered
into transportation agreements for provision of transportation services by Subsidiary
Companies for Company. Copies of the applicable transportation agreements are
attached hereto as Supplements I through III. Each Subsidiary Company shall divide its
segment into one or more Zones as defined in Schedule I, Annex II of the Northern
Pipeline Act and described in subsection 6.2 hereof. Shipper, through its Service
(b)
6.
6.1
TARIFF _PHASE I Effective Date: April 1,2007
Page 55 of 89
Foothills Pine Lines Ltd.
Page 3
Rate Schedule FT
6.2
Agreement, Firm Transportation Service with Company, shall contract to have its gas
transported through one or more of these Zones.
Description
The Subsidiary Companies listed below own and operate the portions of the Phase I gas
transportation system set opposite the name of each such Subsidiary Company.
Subsidiary Companv Zone No. Description
Foothills Pipe Lines 6 From Caroline, Alberta to the
(Alta.) Ltd. Alberta/ Saskatchewan border
near Empress, Alberta.
Length
ftm)
378.49
Foothills Pipe Lines
(South B.C.) Ltd.
Foothills Pipe Lines 9
(Sask.) Ltd.
From Caroline, Alberta to the 124.03
Alberta/B.C. border near
Coleman, Alberta.
From the Alberta/B.C. border 170.7
near Coleman, Alberta to the
B.C.ru.S. border near Kingsgate,
B.C.
From the Alberta/ Saskatchewan 258.97
border near Empress, Alberta to
the Saskatchewan/U. S. border
near Monchy, Saskatchewan.
7.
7.1
CHARACTER OF SERVICE
Firm Transportation Serryice
Gas transported by Company for Shipper under this Rate Schedule FT, Firm
Transportation Service shall not be subject to curtailment or intemrption except as
provided in subsection7.2.4 herein and in the General Terms and Conditions of this Gas
Transportation Tariff.
TARIFF _ PHASE I Effective Date: April l, 2007
Page 56 of 89
Foothills Pipe Lines Ltd.
Page 4
Rate Schedule FT
7.2 Receipt and Delivery Obligations
7.2.1 At each Delivery Point, Company and Shipper shall establish the Maximum Daily
Delivery Quantity ("MDDQ") and shall speciff the portion of such MDDQ to be
received at each Receipt Point. The aforementioned MDDQ and portions thereof
shall be specified in Appendix A to the Service Agreement, Firm Transportation
Service.
7.2.2 At each Delivery Point, identified in Appendix A to the Service Agreement, Firm
Transportation Service, Company is obligated to deliver to Shipper a daily
quantity ofgas which has an aggregate energy content ofall gas received from
Shipper at each Receipt Point destined for such Delivery Point, less Shipper's
share for eachZone of the energy content of Company Use Gas used in the
transportation of such gas on such day.
Shipper's share shall be calculated pursuant to section 8 of the General Terms and
Conditions of this Gas Transportation Tariff.
7.2.3 Notwithstanding subsection 7 .2.2 herein Shipper shall not be allocated a share of
Company Use Gas in respect of Backhaul service.
7.2.4 Company will provide Backhaul service under this Rate Schedule FT, Firm
Transportation Service to Shipper on Zones 8 and 9 only in circumstances where
such service is requested by Shipper and, in Company's judgement, there is
sufficient quantity of gas being received into Company's system to enable such
service to be provided.
7.3 Daily Gas Nominations
7.3.1 Shipper shall advise Company, in writing, of the total daily quantity of gas
nominated by it for each Delivery Point. Such total daily quantity of gas shall
not, subject to Article 1.2 of Shipper's Service Agreement, Firm Transportation
Service, exceed the MDDQ for each such Delivery Point.
Effective Date: April 1,2007
Page 57 of 89
TARIFF -PHASE I
8.
8.1
Page 5
Foothills Pipe Lines Ltd. Rate Schedule FT
7.3.2 Out of such total daily quantity of gas nominated for each Delivery Point, Shipper
shall advise Company of the daily quantity of gas nominated by it for
transportation from each Receipt Point.
7.3.3 Shipper may provide its nomination through written confirmations received by
Company from a downstream carrier. Company shall rely on such confirmations
received from downstream carrier to determine Shipper's nomination quantities at
Delivery Points. For certainty, this would include Shipper's written confirmation
received by Company from Northern Border or Gas Transmission Northwest.
CHARGE FOR SERVICE
The rate used in calculating Shipper's monthly bill for Service under Rate Schedule FT,
Firm Transportation Service in the Zone is the FT Rate.
Shipper's Obligation to Pay
Shipper shall be obligated to pay to Company in respect of each Billing Month, a charge
for services rendered hereunder being the aggregate of Shipper's monthly demand
charges determined in accordance with subsection 8.2.1 hereof and Shipper's Surcharge
determined in accordance with subsection 8.2.2 hereof. Shipper's obligation to pay is not
subject to any adjustment or abatement under any circumstances except as specifically
provided for in section t hereof, and such obligation shall be billed by Company to
Shipper in accordance with section 5 of the General Terms and Conditions of this Gas
Transportation Tariff.
Monthly Charges
8.2.1 Monthly Demand Charge
Shipper's monthly demand charge for a Billing Month shall be the product of:
Effective Date: April 1,2007
Page 58 of 89
8.2
TARIFF _ PHASE I
Page 6
Foothills Pipe Lines Ltd. Rate Scneaute tr't
(a) Shipper's MDDQ as indicated on Schedule A to Shipper's Service Agreement,
Firm Transportation Service for such billing month;
(b) Shipper's Haul Distance for the Zone; and
(c) the FT Rate for the Zone.
8.2.2 Monthly Surcharge
Shipper's surcharge amount, if any, shall be an amount to recognize the recovery of costs
associated with special facilities installed by Company for Shipper agreed to between
Company and Shipper expressed in dollars per month. Such amount shall be set out on
Schedule A to Shipper's Service Agreement, Firm Transportation Service.
8.3 Allocation of Gas Delivered
Notwithstanding any other provision of this Rate Schedule FT, Firm Transportation
Service, and any Service Agreement or the General Terms and Conditions of this Gas
Transportation Tariff, and without regard to how gas may have been nominated, the
aggregate quantity of gas delivered to a Shipper at the Delivery Point during any Billing
Month shall be allocated for billing purposes as follows:
(a) first to service to Shipper under Rate Schedule STFT, Short Term Firm
Transportation Service to a maximum of the aggregate MDDQ for such Delivery
Point under such Rate Schedule STFT, Short Term Firm Transportation Service;
(b) second to service to Shipper under Rate Schedule FT, Firm Transportation
Service to a maximum of the aggregate MDDQ for such Delivery Point under
Rate Schedule FT, Firm Transportation Service; and
(c) third, for Zone 8 andZone 9 to service to Shipper under Rate Schedule IT,
Intemrptible Service and for Zone 6 andZone 7 to Shipper under Rate Schedule
OT, Ovemrn Transportation Service.
Effective Date: April 1,2007TARIFF _PHASE I
Page 59 of 89
8.5
PageT
Foothills Pipe Lines Ltd. Rate Schedule FT
8.4 Charge for Over-Run Gas inT,one 8 and Zone9
In the event that Company determines, in respect of a Billing Month, that Shipper has
tendered for transportation, and Company has transported for Shipper, a quantity of gas
in excess of the MDDQ as indicated on Appendix A of Shipper's Service Agreement,
Firm Transportation Service, Shipper shall pay Company an amount equal to the product
of a quantity of gas equal to such excess and the IT Rate for Service under Rate Schedule
IT, Intemrptible Transportation Service.
Accounting
Company shall maintain books of account in accordance with the requirements of the
National Energy Board and, to the extent not inconsistent with such requirements, in
accordance with generally accepted accounting principles in Canada.
FAILURE TO DELIYER GAS
General
lf Company shall, in any billing month, fail for any reason to make delivery to any
Shipper of the whole or any portion of the quantity of gas nominated by such Shipper
from Company in accordance with such Shipper's Service Agreement, Firm
Transportation Service, such Shipper's obligation to pay Company pursuant to section 8
of Rate Schedule FT, Firm Transportation Service shall be subject only to the
adjustments expressly provided in this section 9.
Make-Up Gas
In the event that Company fails on any day to deliver to Shipper at the Delivery Point the
quantity of gas Shipper has in good faith nominated up to Shipper's MDDQ (unless such
failure is due to planned repairs, maintenance, replacement or other upgrading, or other
work related to Company's transportation system for which Company gave Shippers
notice under subsection 8.8 of the General Terms and Conditions) Shipper shall be
Effective Date: April l, 2007
Page 60 of 89
9.
9.1
9.2
TARIFF -PHASE I
9.3
Page 8
Foothills Pipe Lines Ltd. Rate Schedule FT
entitled, subject to subsection 6.5 of the General Terms and Conditions and within two
years of such failure, to have Company transport such quantities of gas in excess of
Shipper's MDDQ sufficient to make-up such deficiency ("Make-Up Gas") at no
additional demand charge. Demand charges credited to Shipper under subsection 9.4.1
shall be recovered by Company respecting Make-Up Gas.
Allocation of Service
If Company is on any day required to allocate service pursuant to Article I .2 of the
Service Agreement, Firm Transportation Service of two or more Shippers, Company
shall give priority in such allocation to quantities of gas desired to be tendered in respect
to Make-Up Gas over Intemrptible Transportation Service. .
Billing Adjustment
9.4.1 Demand Charge Credit
(a)Subject to subsection 9.4.1(b), if in any month Company is unable to
deliver up to 98 percent of the quantity of gas that Shipper has in good
faith nominated up to the MDDQ times the number of days in such month,
then in respect of such month, a credit shall be applied to the monthly bill
rendered by Company determined according to the following formula:
9.4
Credit FT Rate x Shipper's
Haul
Distance
Shipper's MDDQ Average
Day
Delivery
Quantity*
(b)
*Average Day Delivery Quantity : Deliveries to Shipper in any Month in which
a Demand Charge Credit is applicable, divided by the number of days in that
particular Month.
No credit to the Monthly bill shall be made if Company delivers less than
98 percent of the quantity of gas nominated as a result of planned repairs,
maintenance, replacement or other upgrading, or other work related to
Company's transportation system for which Company gave firm Shippers
TARIFF - PHASE I Effective Date: April 1,2007
Page 61 of89
Foothills Pipe Lines Ltd.
Page 9
Rate Schedule FT
9.5
notice under subsection 8.8 of the General Terms and Conditions on
Company's Facilities or as a result of Shipper being unable to deliver gas
at the Receipt Point or accept gas at the Delivery Point.
Exception
Subsections 9.2 through 9.4 hereof shall not apply to any failure of Company to make
delivery to Shipper of any gas nominated by Shipper pursuant to Shipper's Service
Agreement, Firm Transportation Service if such failure is caused or contributed to by the
failure of Shipper to, or to be able to, deliver to or take delivery from Company of such
gas, or by any other action of Shipper or Persons acting on its behalf which causes or
contributes to such a failure by Company.
RENEWAL RIGHTS IN ZONES 6,7 AND 9
10.1 Availability
Shippers to whom renewal rights are available, shall have the option ("Renewal Option")
of extending the existing term of the Service Agreement, Firm Transportation Service
with respect to all or, if Company agrees, a portion of Shipper's firm capacity rights
beyond the primary term specified in the Service Agreement, Firm Transportation
Service provided that:
Shipper has at any time in the past executed a Service Agreement, Firm
Transportation Service containing a term of at least five consecutive years; such
Service Agreement, Firm Transportation Service or any extensions or
amendments thereto or any amended Service Agreement, Firm Transportation
Service executed in replacement or in substitution therefore, has not terminated
prior to the exercise of the renewal rights granted herein;
Shipper is not in default with respect to any of its obligations under its Service
Agreement(s), Firm Transportation Service;
10.
(a)
(b)
TARIFF _ PHASE I Effective Date: April 1,2007
Page 62 of 89
Foothills Pipe Lines Ltd.
Page l0
Rate Schedule FT
(c)If requested by Company, Shipper has provided Financial Assurances in
accordance with subsection 5.8.1 of the General Terms and Conditions of this Gas
Transportation Tariff; and
Shipper provides Company, at the time the notice referred to in subsection 10.2.1
or 10.2.3 hereof is provided to Company, evidence satisfactory to Company that
Shipper has obtained or will be able to obtain appropriate upstream and
downstream firm transportation arrangements.
(d)
10.2 Procedures
10.2.1 Company may give Shipper notice ("Renewal Notice") not more than 5 years and
not less than six (6) months prior to termination of Shipper's Service Agreement,
Firm Transportation Service that Shipper must exercise the Renewal Option.
Shipper has the right to renew the Service Agreement, Firm Transportation
Service prior to this Renewal Notice being given upon written notice to Company.
As long as at least five (5) years remain in the term of the Shipper's Service
Agreement, Firm Transportation Service then such Renewal Notice cannot be
given by Company. Shipper has the right to extend its Service Agreement, Firm
Transportation Service one year at a time to maintain a term of at least five (5)
years and thereby remain outside the period in which a Renewal Notice can be
given.
10.2.2 Once a Renewal Notice is given to Shipper, Shipper shall have ten (10) business
days from the date of the Renewal Notice to provide Company with a written
notice from Shipper of Shipper's election to extend the term of the Service
Agreement, Firm Transportation Service for a period of at least five (5) years.
10.2.3 If Shipper fails to provide a written request or indicates to Company that it does
not wish to renew its capacity in accordance with section 10.2.2, the Company
may make the capacity available to other parties in an Open Season in accordance
with subsection 4.1 of the Capacity Allocation procedures of this Gas
Transportation Tariff.
Effective Date: April 1,2007
Page 63 of 89
TARIFF -PHASE I
Foothills Pipe Lines Ltd.
Page 11
Rate Schedule FT
10.2.4 Upon receipt of all bids for the capacity pursuant to the Open Season in
accordance with subsection 4.1 of the Capacity Allocation procedures of this Gas
Transportation Tariff, the Company shall select the highest net present value
bid(s) and notify Shipper of the terms of the successful bid(s) within l5 business
days of the close of the Open Season. Shipper may retain this capacity if Shipper
agrees to match the highest net present value bid(s) obtained in the Open Season.
In the event that such bid(s) is longer than five (5) years, Shipper may retain the
capacity by extending its Service Agreement by a minimum of five (5) years
provided that such notice is made in writing to Company within l0 business days
following the date of the bid notification from Company. If no bids are received,
Company may accept other terms of renewal if requested in writing from Shipper,
notwithstanding that if the remaining term is less than five (5) years, notice may
be given pursuant to subsection 10.2.
10.2.5 Following receipt of Shipper's written request in accordance with either
subsections 10.2.1,10.2.2 or 10.2.4, Company will, within 5 business days,
provide Shipper with an amendment to the Service Agreement, Firm
Transportation Service setting out the renewal term. Shipper shall execute and
return the amendment to the Service Agreement, Firm Transportation Service to
Company within fifteen (15) business days of receipt from Company, failing
which Shipper's Renewal Option terminates.
10.3 Shipper shall have Renewal Rights to be exercised in the same manner and upon the
same terms and conditions as set forth above during any renewal term.
11.RENEWAL RIGHTS IN ZONE 8
11.1 Availability
Shippers in Zone 8 shall be entitled to renew all or, if Company agrees, a portion of
service under a Service Agreement, Firm Transportation Service if Shipper gives notice
to Company of such renewal at least one ( I ) year prior to termination of Shipper' s
Service Agreement, Firm Transportation Service. If Shipper does not provide such
Effective Date: April 1,2007
Page 64 of 89
TARIFF _ PHASE I
Foothills Pipe Lines Ltd.
Page12
Rate Schedule FT
notice, service shall terminate on the date specified in Shipper's Service Agreement, Firm
Transportation Service.
ll.2 Procedures
Shipper's notice to renew in Zone 8 pursuant to subsection I l.l shall be irrevocable for
the year immediately prior to the termination of service specified in Shipper's Service
Agreement, Firm Transportation Service.
Any renewal of service is subject to the Financial Assurances provisions in subsection 5.8
of the General Terms and Conditions.
Shipper's notice shall speciff a renewal term in Zone 8 of not less than one (l) year
consisting of increments of whole months.
Effective Date: April l, 2007
Page 65 of 89
TARM'F _PHASE I
NOVA Gas Transmission Ltd.
Page I
FT-R
Rate Schedule
r.0
t.l
2.0
2.1
RATE SCHEDULE FT.R
FIRM TRANSPORTATION - RECEIPT
DEFINITIONS
The capitalized terms used in this Rate Schedule have the meanings attributed to them in
the General Terms and Conditions of the Tariff unless otherwise defined in this Rate
Schedule.
SERVICE DESCRIPTION AI\ID AVAILABILITY
Subject to the stated terms and conditions, service under Rate Schedule FT-R shall mean
the receipt of gas from Customer at Customer's Receipt Points (the "Service") which
includes transportation of gas that Company determines necessary to provide services
under the Tariff.
Provided however, on any day, Service at the Empress or McNeill Receipt Points shall
not exceed the greater of:
(i)
(ii)
100 GJs; or
the total volume of gas delivered to Customer at such point under Rate Schedules
FT-D, FT-DW,IT-D, STFT, LRS and LRS-3 on such day.
2.2 The Service is available to any Customer that has executed a Service Agreement and
Schedule of Service under Rate Schedule FT-R. A standard form Service Agreement for
Service under this Rate Schedule FT-R is attached.
Effective Date: January 1,2014 Page oo oI u9
NOVA Gas Transmission Ltd.
Page2
FT.R
Rate Schedule
3.0 PRICING
3.1 Subject to paragraph3.2, the rate used in calculating Customer's monthly demand charge
under each of Customer's Schedules of Service for Service under Rate Schedule FT-R is
the FT-R Demand Rate.
3.2 If the Primary Term plus the Secondary Term of any of Customer's Schedules of Service
for any new Service or any renewed Service under Rate Schedule FT-R is:
(D five (5) years or greater the Price Point shall be 95Yo (Price Point "A");
(ii) at least three (3) years but less than five (5) years the Price Point shall be 100%
(Price Point "8"); and
(iiD at least one (l) year but less than three (3) years the Price Point shall be l05o/o
(Price Point "C").
4.0 CHARGE FOR SERYICE
4.1 Aggregate of Customerrs Monthly Demand Charges
The aggregate of Customer's monthly demand charges for a Billing Month for Service
under Rate Schedule FT-R shall be equal to the sum of the monthly demand charges for
each of Customer's Schedules of Service under Rate Schedule FT-R, determined as
follows:
MDC = I (FxPl(t,+l,\ C )
Elfective Date: January 1,2014 Page 67 of 69
NOVA Gas Transmission Ltd.
Page 3
FT.R
Rate Schedule
Where:
66Mf)C" : the aggregate of the demand charges applicable to such Schedule
of Service for such Billing Month;
66F" = the FT-R Demand Rate applicable to such Schedule of Service;
((P" = the applicable Price Point for such Schedule of Service;
6(A" : each Receipt Contract Demand in effect for all or a portion of such
Billing Month for such Schedule of Service;
668" = the number of days in such Billing Month that Customer was
entitled to such Receipt Contract Demand under such Schedule of
Service; and
$Cr) : the number of days in such Billing Month.
4,2 Aggregate of Customer's Surcharges
The aggregate of Customer's Surcharges for a Billing Month shall be equal to the sum of
all Surcharges set forth in the Table of Rates, Tolls and Charges applicable to each of
Customer's Schedules of Service under Rate Schedule FT-R.
4.3 Aggregate of Customer's Over-Run Gas Charges
The aggregate of Customer's charges for Over-Run Gas in a Billing Month for Service
under all Rate Schedules shall be equal to the sum of the monthly charges for Over-Run
Gas for each Receipt Point at which Customer is entitled to Service under any Rate
Schedule, determined as follows:
MOC:VxZ
Effective Date: January 1,2014 Page 66 0r 69
NOVA Gas Transmission Ltd.
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FT.R
Rate Schedule
Where:
"MOC" : the monthly charge for Over-Run Gas at such Receipt Point;
66V" = total volume of gas allocated to Customer by Company as Over-
run Gas in accordance with paragraph 4.6 for Service under all
Rate Schedules at such Receipt Point for such Billing Month; and
'(Z)' : the IT-R Rate at such Receipt Point.
4.4 The calculation of Customer's charge for Over-Run Gas in paragraph 4.3 shall not take
into account Customer's [nventory on the last day of the Billing Month.
4.5 Aggregate Charge For Service
Customer shall pay for each Billing Month:
(i) the sum of the amounts calculated in accordance with paragraphs 4.1, 4.2, and
4.3; less
(ii) the amount, if any, calculated in accordance with the Terms and Conditions
Respecting Relief for Mainline Capacity Restrictions in Appendix "B" of the
Tariff.
4.6 Allocation of Gas Received
Notwithstanding any other provision of this Rate Schedule, any Service Agreement or the
General Terms and Conditions of the Tariff, and without regard to how gas may have
been nominated, the aggregate volume of gas received from Customer at a Receipt Point
shall be allocated for billing purposes as follows:
Effective Date: January 1,2014 Page o9 or dc
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Page 5
FT.R
Rate Schedule
(i)
(ii)
first to service to Customer under Rate Schedules LRS and LRS-3 to a maximum
of such Customer's LRS Contract Demand for such Receipt Point under such Rate
Schedule LRS and to a maximum of such Customer's LRS-3 Contract Demand for
such Receipt Point under such Rate Schedule LRS-3;
secondly to Service to Customer under Rate Schedule FT-R to a maximum of
such Customer's Receipt Contract Demand for such Receipt Point under Rate
Schedule FT-R;
thirdly to service to Customer under Rate Schedule FT-RN to a maximum of such
Customer's Receipt Contract Demand for such Receipt Point under Rate Schedule
FT-RN; and
fourthly to service to Customer under Rate Schedule IT-R at such Receipt Point.
lf Customer is not entitled to service under Rate Schedule IT-R at such Receipt
Point, gas shall be allocated as Over-Run Gas and charged in accordance with
paragraph 4.3.
(iii)
(iv)
5.0
5.1
TERM OF SERYICE
Term of a Schedule of Service
If, in the provision of new Service, Company determines that:
(D no new Facilities are required to be installed or constructed at any Receipt Point
to provide the Service requested, the term of the Schedule of Service shall be a
Secondary Term equal to the term requested by Customer with the minimum term
being three (3) years; or
Effective Date: January 1,2014 Page /u or u9
NOVA Gas Transmission Ltd.
Page 6
FT.R
Rate Schedule
(ii)new Facilities are required to be installed or constructed at any Receipt Point to
provide the Service requested, the term of the Schedule of Service shall be equal
to the sum of:
(a)
(b)
the Primary Term; and
a Secondary Term equal to the Secondary Term requested by Customer
with the minimum Secondary Term being three (3) years.
5.2
5.3
The Price Point for the term shall be determined in the manner described in paragraph
3.2.
If the number of years calculated for the Primary Term exceeds fifteen (15) years the
Primary Term shall be fixed at fifteen (15) years and a Surcharge, determined under the
Criteria for Determining Primary Term in Appendix "E" of the Tariff, shall be applied in
respect of such Service.
Term of Service Agreement
Customer's Service Agreement shall terminate on the latest Service Termination Date of
Customer's Schedules of Service for Service under Rate Schedule FT-R.
6.0 CAPACITY RELBASE
6.1 If Customer desires a reduction of Customer's Receipt Contract Demand for all or any
portion of its Service under a Schedule of Service under Rate Schedule FT-R, Customer
shall give Notice to Company of its request for such reduction speciffing the particular
Receipt Point, Schedule of Service and the Receipt Contract Demand available to any
other Person who requires Service under Rate Schedule FT-R. Company shall not have
any obligation to find any Person to assume the Receipt Contract Demand Customer
5.4
Effective Date: January 1,2014 Page /1 or69
NOVA Gas Transmission Ltd.
PageT
FT-R
Rate Schedule
proposes to make available. If after Notice is given to Company a Person is found who
agrees to assume the Receipt Contract Demand Customer proposes to make available,
together with any applicable Surcharge, Company may reduce Customer's Receipt
Contract Demand under such Schedule of Service, on terms and conditions satisfactory to
Company, by an amount equal to the Receipt Contract Demand specified in a new
Schedule of Service, executed by Company and such Person. Notwithstanding such
reduction, Customer shall at Company's sole option either:
continue to pay any Surcharge until the Service Termination Date as described in
the applicable Schedule of Service (unless any other Person acceptable to
Company has agreed to pay such Surcharge); or
in the event that Company retires any Facilities required to provide such Service,
pay to Company within a time determined by Company, an amount equal to the
net book value ofsuch Facilities adjusted for all costs and expenses associated
with such retirement.
RELIEF FOR MAINLINE RESTRICTIONS
Company will grant relief to a Customer entitled to Service under Rate Schedule FT-R, in
accordance with the Terms and Conditions Respecting Relief for Mainline Capacity
Restrictions in Appendix "B" of the Tariff.
(i)
(ii)
7.0
7.1
Effective Date: January 1,2014 Page tzot69
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Page 8
FT.R
Rate Schedule
8.0
8.1
TRANSFER OF SERVICE
Transfers Between Receipt Points Within the Same Project Area
If Customer desires to transfer all or any portion of Service under a Schedule of Service
from a Receipt Point within a Project Area to a Receipt Point within the same Project
Area, Customer shall give Notice to Company of Customer's request for such transfer
speciffing the Receipt Points, the Schedule of Service and the portion of the Receipt
Contract Demand that Customer wishes to transfer.
Company is under no obligation to permit the transfer requested in paragraph 8.1, but
may permit such transfer provided that:
(i) Company determines that sufficient capacity exists in the Facilities to
accommodate the transfer;
(iD Company determines that the construction or installation of new Facilities that are
directly attributable to the transfer is not required;
(iiD the transfer does not occur during the Primary Term of the Schedule of Service;
8.2
(iv)
(v)
(vi)
the Price Point in effect for Service under the Schedule of Service, from which
Customer wishes to transfer Service at the time of the transfero applies to the new
Schedule of Service for the Service that has been transferred;
the FT-R Demand Rate applicable to Service under the Schedule of Service that
has been transferred shall be the FT-R Demand Rate in effect at the Receipt Point
to which the Service under the Schedule of Service has been transferred; and
Customer executes a ffansfer of Service agreement.
Eflective Date: January 1,2014 Page 73 ol 69
NOVA Gas Transmission Ltd.
Page 9
FT.R
Rate Schedule
8.3 Transfers Between Receipt Points in Different Project Areas
If Customer desires to transfer all or any portion of Service under a Schedule of Service
from a Receipt Point within a Project Area to a Receipt Point in a different Project Area,
Customer shall give Notice to Company of Customer's request for such transfer
specifying the Receipt Points, the Schedule of Service and the portion of the Receipt
Contract Demand that Customer wishes to transfer.
Company is under no obligation to permit the transfer requested in paragraph 8.3, but
may permit such transfer provided that:
8.4
(i)
(ii)
(i ii)
(iv)
Company determines that sufficient capacity exists in the Facilities to
accommodate the transfer;
Company determines that the construction or installation of new Facilities that are
directly attributable to the transfer is not required;
the transfer does not occur during the Primary Term of the Schedule of Service;
three (3) years are added to the balance of Customer's Secondary Term for the
new Schedule of Service (the "New Term") for the Service that has been
transferred;
the Price Point for Service under the new Schedule of Service for the Service that
has been transferred shall be determined in the manner described in paragraph 3.2
using the New Term;
the FT-R Demand Rate applicable to the Service under the Schedule of Service
that has been transferred shall be the FT-R Demand Rate in effect at the Receipt
Point to which Service under the Schedule of Service has been transferred; and
(v)
(vi)
Effective Date: January 1,2014 F'age /4 or 69
NOVA Gas Transmission Ltd.
Page 10
FT.R
Rate Schedule
8.5
(vii) Customer executes a transfer of Service agreement.
Transfers Between Receipt Points and Delivery Points
A Customer entitled to receive Service under Rate Schedule FT-R shall not be entitled to
transfer all or any portion of Service under Rate Schedule FT-R to a Delivery Point.
TERM SWAPS
Term Swap Between Receipt Points Within the Same Project Area
If Customer desires to swap the Service Termination Date of a Schedule of Service with
the Service Termination Date of another Schedule of Service and the Receipt Points for
the Schedules of Service are within the same Project Area, Customer shall give Notice to
Company of Customer's request for such swap specifying the particular Receipt Points,
the Service Termination Dates and the Schedules of Service, if necessary, that Customer
wishes to swap.
Company is under no obligation to permit the swap requested in paragraph 10.1, but may
permit such swap provided that:
Company determines that sufficient capacity exists in the Facilities to
accommodate the swap;
Company determines that the construction or installation of new Facilities that are
directly attributable to the swap is not required;
(iii) the swap does not occur during the Primary Term of the Schedule of Service;
9.0
9.1
9.2
(i)
(i i)
Effective Date: January 1,2014 Page 75 of 89
NOVA Gas Transmission Ltd.
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FT.R
Rate Schedule
(iv)the Receipt Contract Demand and the FT-R Demand Rate;
(a) at each Receipt Point; and
(b) for each Service Termination Date
do not change as a result of the swap;
the Price Point in effect for each Schedule of Service after the swap shall be the
Price Point in effect for the other Schedule of Service immediately prior to the
time the Service Termination Dates were swapped; and
Customer executes new Schedules of Service.
(v)
(vi)
9.3 Term Swaps Between Receipt Points in Different Project Areas
If Customer desires to swap the Service Termination Date of a Schedule of Service with
the Service Termination Date of another Schedule of Service and the Receipt Points for
the Schedules of Service are in different Project Areas, Customer shall give Notice to
Company of Customer's request for such swap speciffing the particular Receipt Points,
the Service Termination Dates and the Schedules of Service, if necessary, that Customer
wishes to swap.
Company is under no obligation to permit the swap requested in paragraph 10.3, but may
permit such swap provided that:
(i) Company determines that sufficient capacity exists in the Facilities to
accommodate the swap;
9.4
Effective Date: January l, 2014 Fage /o or uv
NOVA Gas Transmission Ltd.
Page12
FT.R
Rate Schedule
(ii) Company determines that the construction or installation of new Facilities that are
directly attributable to the swap is not required;
(iiD the swap does not occur during the Primary Term of the Schedule of Service;
(iv) the Receipt Contract Demand and the FT-R Demand Rate:
(a) at each Receipt Point; and
(b) for each Service Termination Date
do not change as a result of the swap;
(v) subject to subparagraph 9.4(vi), the Price Point in effect for each Schedule of
Service after the swap shall be the Price Point in effect for the other Schedule of
Service immediately prior to the time the Service Termination Dates were
swapped;
(vi) three (3) years are added to the balance of Customer's Secondary Term for each
Schedule of Service (the 'New Term") if the remaining term of either of the
Schedules of Service is less than three (3) years and the Price Point that shall
apply to each Schedule of Service shall be the Price Point determined in the
manner described in paragraph 3.2 using the New Term for such Schedules of
Service; and
(vii) Customer executes new Schedules of Service.
Effective Date: January 1,2014 Hage // oruv
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Page 13
FT-R
Rate Schedule
9.5 Term Swaps Between Schedules of Service Under Rate Schedule FT-R and other
Schedules of Service
Except as provided in article 9, a Customer entitled to receive Service under Rate
Schedule FT-R shall not be entitled to swap the Service Termination Date of any
Schedule of Service under Rate Schedule FT-R with the Service Termination Date under
any Schedule of Service.
IO.O TITLE TRANSFERS
10.1 A Customer entitled to receive Service under Rate Schedule FT-R may transfer all or a
portion of Customer's Inventory to another Customer or may accept a transfer of all or a
portion of Customer's Inventory from another Customer provided such Customer is
entitled to receive service under any Rate Schedule that permits title transfers and such
title transfer is in accordance with the Terms and Conditions of Service Respecting Title
Transfers in Appendix "C" of the Tariff.
11.0 RENEWAL OF SERVICE
11.1 RenewalNotification
Customer shall be entitled to renew all or any portion of Service under a Schedule of
Service under Rate Schedule FT-R as Service under either Rate Schedule FT-R or Rate
Schedule FT-P, if Customer gives Notice to Company of such renewal at least one ( I )
year prior to the Service Termination Date. If Customer does not speciff which Rate
Schedule the Service is to be renewed under, the Service shall be renewed under Rate
Schedule FT-R. If Customer does not provide such Notice, the Service shall expire on
the Service Termination Date.
Effective Date: January 1,2014 Hage //6 OT 6V
NOVA Gas Transmission Ltd.
Page 14
FT-R
Rate Schedule
11.2 IrrevocableNotice
Customer's Notice to renew pursuant to paragraph I l.l shall be irrevocable one (l) year
prior to the Service Termination Date.
Any renewal of Service is subject to the Financial Assurances provisions in Article l0 of
the General Terms and Conditions.
11.3 Renewal Term
Customer's Notice shall speciff a renewal term of not less than one (l) year consisting of
increments of whole months. The Price Point for the renewal term shall be determined in
the manner described in paragraph 3.2 based on the length of the renewal term requested
by Customer.
I2.O APPLICATION FOR SERVICE
l2.l Applications for Service under this Rate Schedule FT-R shall be in such form as
Company may prescribe from time to time.
13.0 GENERAL TERMS AI\[D CONDITIONS
f3.1 The General Terms and Conditions of the Tariff and the provisions of any Service
Agreement for Service under Rate Schedule FT-R are applicable to Rate Schedule FT-R
to the extent that such terms and conditions and provisions are not inconsistent with this
Rate Schedule.
Effective Date: January 1,2014 Page 79 of 69
NOVA Gas Transmission Ltd.
Page 15
FT-R
Service Agreement
SERYICE AGREEMENT
RATE SCIMDULE FT.R
BETWEEN:
NOVA Gas Transmission Ltd., a body corporate having an office in
C algary, A lberta ("Company")
-and-
., a body corporate having an office in ., . ("Customer")
IN CONSIDERATION of the premises and the covenants and agreements in this Service
Agreement, the parties covenant and agree as follows:
Customer acknowledges receipt of a current copy of the Tarifl.
The capitalized terms used in this Service Agreement have the meanings attributed to
them in the General Terms and Conditions of the Tariff, unless otherwise defined in this
Service Agreement.
Customer requests and Company agrees to provide Service pursuant to Rate Schedule
FT-R in accordance with the attached Schedules of Service. The Service will commence
on the Billing Commencement Date and will terminate, subject to the provisions of this
Service Agreement, on the Service Termination Date.
Customer agrees to pay to Company each Billing Month, for all Service rendered under
this Service Agreement, an amount equal to the aggregate charges for Service described
in Rate Schedule FT-R.
t.
2.
3.
4.
Effective Date: January l, 2014 Page uu or u9
NOVA Gas Transmission Ltd.
Page 16
FT.R
Service Agreement
5.Customer shall:
provide such assurances and information as Company may reasonably require
respecting any Service to be provided pursuant to this Rate Schedule FT-R
including, without limiting the generality of the foregoing, an assurance that
necessary arrangements have been made among Customer, producers of gas for
Customer, purchasers of gas from Customer and any other Person relating to such
Service, including all gas purchase, gas sale, operating, processing and common
stream arrangements; and
at Company's request provide Company with an assurance that Customer has
provided the Person operating facilities upstream of any Receipt Point in respect
of which Customer has the right to receive service with all authorizations
necessary to enable such Person to provide Company with all data and
information reasonably requested by Company for the purpose of allocating
volumes of gas received by Company among Company's Customers and to bind
Customer in respect of all such data and information provided.
If Customer fails to provide such assurances and information forthwith following request
by Company, from time to time, Company may at its option, to be exercised by Notice to
Customer, suspend the Service to which such assurances and information relate until
such time as Customer provides the assurances and information requested, provided
however that any such suspension of Service shall not relieve Customer from any
obligation to pay any rate, toll, charge or other amount payable to Company.
Customer acknowledges that the Facilities have been designed based on certain
assumptions and forecasts described in Company's Annual Plan, and that intemrption
and curtailment of Service may occur if the aggregate gas volume actually received or the
aggregate gas volume actually delivered at the Facilities is different than forecast.
(a)
(b)
6.
Effective Date: January l, 2014 Page 61 ot E9
7.
NOVA Gas Transmission Ltd.
PagelT
FT-R
Service Agreement
Every notice, request, demand, statement, bid or bill provided for in Rate Schedule FT-R,
this Service Agreement and the General Terms and Conditions, or any other notice which
either Company or Customer may desire to give to the other (collectively referred to as
"Notice") shall be in writing and each of them and every payment provided for shall be
directed to the Person to whom given, made or delivered at such Person's address as
follows:
Customer:
a
Attention:
Fax: .
Company:
o
Attention: Customer Account Representative
Fax: .
Notice may be given by fax or other telecommunication and any such Notice shall be
deemed to be given four (4) hours after transmission. Notice may also be given by
personal delivery or by courier and any such Notice shall be deemed to be given at the
time of delivery. Any Notice may also be given by prepaid mail and any such Notice
shall be deemed to be given four (4) business days after mailing, Saturdays, Sundays and
statutory holidays excepted. In the event of disruption of regular mail, every payment not
made electronically shall be personally delivered, and any other Notice shall be given by
one of the other stated means.
Effective Date: January 1,2014 Page uz or 6c
NOVA Gas Transmission Ltd.
Page 18
FT.R
Service Agreement
(a) Notwithstandingtheforegoing:
Company may give any Notice on the Website; and
Company and Customer shall give Notice for the matters listed in the
Notice Schedule for Electronic Commerce in Appendix "F" of the Tariff
via the Website unless the Website is inoperative, in which case Notice
shall be given by any other alternative means set out herein.
Any Notice posted on the Website shall be deemed to be given one (l) hour after
posting.
(b) Notice may also be given by telephone followed immediately by fax, personal
delivery, courier or prepaid mail, and in the case of Company, by posting on the
Website, and any Notice so given shall be deemed to have been given as of the
date and time of the telephone Notice.
8. The terms and conditions of Rate Schedule FT-R, the General Terms and Conditions and
Schedule of Service under Rate Schedule FT-R are by this reference incorporated into
and made apart of this Service Agreement.
IN WITNESS WHEREOF the parties have executed this Service Agreement by their proper
signing officers duly authorizedinthat behalf all as of the o day 6f o, o.
Per:
Per:
NOVA Gas Transmission Ltd.
Per :
(i)
(ii)
Effective Date: January 1,2014
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TRANSPORTATION SERVICE . SOUTHERN
DEFINITIONS
1. ln this Toll Schedule, the following term shall have the following meaning:
(a) "Enhanced T-South " means Transportation Service - Southern provided
pursuant to a Service Agreement under which gas is to be delivered to the
Huntingdon Delivery Area and, subject to the fulfillment of the conditions specified in
the Service Agreement, to the Kingsgate Export Point;
(b) "Kinqsqate Exoort P ' means the point on the international boundary between
Canada and the United States of America near Kingsgate, British Columbia, where
the Foothills Pipe Lines (South BC) Ltd. pipeline facilities connect with the pipeline
facilities of Gas Transmission Northwest Corporation; and
(c) "Service Term" means in respect of each Firm Transportation Service - Southern
specified in a Firm Service Agreement, the term of each such Firm Transportation
Service - Southern as determined in accordance with Section 3.
All other terms used in this Toll Schedule shall have the same meaning as set forth in the
General Terms and Conditions.
APPLICATION
2. This Toll Schedule applies to all Firm Transportation Service - Southern, AOS and
lnterruptible Transportation Service - Southern, including lmport Backhaul Service, provided
by Westcoast on facilities in Zone 4 under the provisions of a Firm Service Agreement or an
lnterruptible Service Agreement into which the General Terms and Conditions and this Toll
Schedule are incorporated by reference.
3. For all purposes of this Toll Schedule, the Demand Toll applicable to any Firm
Transportation Service - Southern provided pursuant to a Firm Service Agreement shall be
determined based upon the Service Term, and the Service Term for each such service shall
be determined as follows:
(a) in the case of each Firm Transportation Service - Southern provided for in a Firm
Service Agreement entered into by a Shipper with Westcoast prior to November 1,
2005, the number of whole years remaining in the term of each such service as of
November 1,2005;
(b) in the case of each Firm Transportation Service - Southern provided for in a Firm
Service Agreement entered into by a Shipper with Westcoast after November 1,
2005, the number of whole years in the term of each such service specified in the
Firm Service Agreement;
(c) in the case of each such Firm Transportation Service - Southern which is renewed
by a Shipper after November 1, 2005 in accordance with Section 2.06 of the General
Page 85 of 89
Terms and Conditions, the number of whole years in the renewal term of each such
service, with effect from the first day of the renewal term; and
(d) in the case of each Firm Transportation Service - Southern provided for in a Firm
Service Agreement which is extended by the Shipper and Westcoast after
December 31, 2005, the number of whole years remaining in the term of each such
service, including the period of the extension, with effect from the first day of the
month immediately following the execution by the Shipper of an amendment to the
Firm Service Agreement providing for such extension.
MONTHLY BILL. FIRM TRANSPORTATION SERVICE - SOUTHERN
4. The amount payable by a Shipper to Westcoast in respect of Firm Transportation Service -
Southern provided in any month pursuant to a Firm Service Agreement shall be an amount
equalto:
(a) the product obtained by multiplying the Contract Demand for Firm Transportation
Service - Southern specified in the Firm Service Agreement by the applicable
Demand Toll specified in Appendix A for Firm Transportation Service - Southern; and
(b) the amount of tax on fuel gas consumed in operations payable under the Motor Fuel
Tax Act (British Columbia) and the Carbon Tax Act (British Columbia) which is
allocated to Shipper by Westcoast for the month,
less the amount of any Contract Demand Credits to which the Shipper is entitled for the
month pursuant to the General Terms and Conditions.
MONTHLY BILL . AOS, INTERRUPTIBLE TRANSPORTATION SERVICE . SOUTHERN AND
IMPORT BACKHAUL SERVICE
5. lf on any day Shipper has unutilized Firm Transportation Service - Southern at a Delivery
Point in Zone 4 and would incur on such day tolls for AOS and lnterruptible Transportation
Service, other than lmport Backhaul Service, at that Delivery Point or at any other Delivery
Point in Zone 4, then, notwithstanding the provisions of the General Terms and Conditions
and for the sole purpose of determining the amount of the Commodity Tolls payable by
Shipper in accordance with this Toll Schedule for AOS and lnterruptible Transportation
Service - Southern, the following rules shall apply:
(a) firstly, in the case where Shipper would othenrise incur tolls on such day for AOS and
lnterruptible Transportation Service - Southern at a Delivery Point where Shipper has
unutilized Firm Transportation Service - Southern, Shipper shall be deemed to have
utilized Firm Transportation Service at such Delivery Point on such day in respect of a
volume of gas not exceeding the volume of unutilized Firm Transportation Service at
such Delivery Point;
(b) secondly, in the case where a Delivery Point at which Shipper has unutilized Firm
Transportation Service - Southern is within the Huntingdon Delivery Area and Shipper
has any remaining volume of unutilized Firm Transportation Service at such Delivery
Point after applying the rule set out in paragraph (a) above, then Shipper shall be
deemed to have made a diversion on such day pursuant to Section 7.01(a) of the
Page 86 of 89
General Terms and Conditions of a volume of gas not exceeding the amount of the
remaining volume of unutilized Firm Transportation Service, from that Delivery Point
to any other Delivery Point within the Huntingdon Delivery Area at which Shipper
would otherwise incur tolls for AOS and lnterruptible Transportation Service -
Southern;
(c) thirdly, if Shipper has any remaining volume of unutilized Firm Transportation Service
- Southern at any Delivery Point after applying the rules set out in paragraphs (a) and
(b) above, then Shipper shall be deemed to have made a diversion on such day
pursuant to Section 7.01(c) of the General Terms and Conditions of a volume of gas
not exceeding the amount of such remaining volume of unutilized Firm Transportation
Service from such Delivery Point to the nearest Downstream Delivery Point at which
Shipper would otherwise incur tolls for AOS and lnterruptible Transportation Service -
Southern; and
(d) fourthly, if Shipper has any remaining volume of unutilized Firm Transportation
Service - Southern at any Delivery Point after applying the rules set out in paragraphs
(a), (b) and (c) above, then Shipper shall be deemed to have made a diversion on
such day pursuant to Section 7.01(b) of the General Terms and Conditions of a
volume of gas not exceeding the amount of such remaining volume of unutilized Firm
Transportation Service, from such Delivery Point to the nearest Upstream Delivery
Point at which Shipper would otherwise incur tolls for AOS and lnterruptible
Transportation Service - Southern.
6. The amount payable by a Shipper to Westcoast in respect of AOS, lnterruptible
Transportation Service - Southern, and lmport Backhaul Service provided on each day in a
month shall be an amount equalto the sum of:
(a) the product obtained by multiplying the applicable Commodity Toll specified in
Appendix A for AOS, lnterruptible Transportation Service - Southern and lmport
Backhaul Service, respectively, by the Receipt Volume for such AOS or lnterruptible
Transportation Service - Southern (as determined after applying the rules set out in
Section 5) or for such lmport Backhaul Service, respectively, at the point from which
the residue gas is sourced, which is thermally equivalent to the volume of residue gas
(i) delivered to or for the account of Shipper at the Delivery Point, or (ii) transmitted
through Zone 4 for the account of Shipper on each such day during the month;
(b) the product obtained by multiplying the difference between the Commodity Tolls
specified in Section 7.03 of the General Terms and Conditions by the volume of gas
deemed to be diverted to a Downstream Delivery Point in accordance with Section
4(c) on each such day during the month; and
(c) the amount of tax on fuel gas consumed in operations payable under the Motor Fuel
Tax Act (British Columbia) and the Carbon Tax Act (British Columbia) which is
allocated to Shipper by Westcoast for each day in the month.
Page 87 of 89
APPENDIX A
DEMAND AND COMMODITY TOLLS
TRANSPORTATION SERVICE - SOUTHERN
Firm Transportation Seruice - Southern
Demand Tolls
g/103m3/mo.
PNG lnland Huntingdon
Service Term Delivery Point Delivery Area Delivery Area* Huntingdon**
1 year
2 years
3 years
4 years
5 years or more
92.99
90.28
87.57
86.67
85.76
244.37
237.25
230.13
227.76
225.39
410.45
398.49
386.54
382.55
378.57
FortisBC
Kingsvale to
166.08
161.24
156.40
154.79
153.'t8
* To be increased to the percentage amount of the applicable toll specified in a Service Agreement for
Enhanced T-South Service
** For Firm Transportation Service - Southern provided by Westcoast pursuant to a Firm Service Agreement
dated April 15,2002 between Westcoast and FortisBC Energy lnc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
Authorized Overrun Seruice
FortisBC
Kingsvale toHuntingdon
Delivery Point Delivery Area Delivery Area Huntingdon*
November to March
April to October
" For AOS provided by Westcoast pursuant to a Firm Service Agreement dated April 15,2002 between
Westcoast and FortisBC Energy lnc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
PNG
3.693
2.955
lnland
9.706
7.765
16.302 6.596
13.041 5.277
Page 88 of 89
l nterruptible Transportation Service - Southern
l
i
I
I
l
I
I
I
I
j
I
I
I
I
I
Commoditu Tolls
$/103;3
Months
PNG lnland
Delivery Point Delivery Area
Huntingdon
Delivery Area
19.478
14.776
FortisBC
Kingsvale to
Huntingdon
7.881
5.979
November to March
Aprilto October
4.413
3.348
11.596
8.797
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fue! Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
lmport Backhaul Service
Commoditv Tolls
$/103;3lnland PNG
Deliverv Area Delivery Point
Compressor
Station No.2
November to March
Aprilto October
7.882
5.979
15.065
11.428
19.478
14.776
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
Page 89 of 89