20140915Application & Exhibits.pdf

Avista Corp.
l4l I East Mission P.O.Box3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
September 12,2014
State ofldaho
Idaho Public Utilities Commission
47 2 W. Washington Street
Boise, Idaho 83702-5983
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Case No. AVU-G-I4 -O!lXvice No. 14-01-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 tariffsheets:
Tkentieth Revision Sheet 150 canceling Nineteenth Revision Sheet 150
Sixteenth Revision Sheet 155 canceling Fifteenth Revision Sheet 155
The Company requests that the proposed tariffsheets be made effective November 1,2014.
These tariff sheets reflect the Company's annual Purchased Gas Cost Adjustment ("PGA"). If these
tariff sheets are approved as filed, the Company's annual revenue will decrease by approximately
$1.6 million or approximately 2.1%. 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 60 therms per month will see decrease of $1.16 per month, or approximately 2.0Yo. The present
bill for 60 therms is $59.48 while the proposed bill is $58.32. The Company will issue a notice to its
customers through a bill insert starting on September 17,2014 and ending on October 15,2014. A
copy of the bill insert has been included in the Company's filing.
If you have any questions regarding this filing, please contact Patrick Ehrbar at [phone] or
Ryan Finesilver at [phone].
Sincerely,C//Davif,J. Meyer
Vice President and Chief Counsel for Regulatory and Governmental Affairs
Enclosures
Xr:CL l! '. '
BEFORE Trm, rDAHO PUBLTC UTILITIES COMMISSION ?filti sfp l5 AH g: 0g
i['Ai;[ | :-li;., .
uT lLtTlE$ 00to4ii isSlci,
IN THE MATTER OF THE APPLICATION OF )
AVTSTA UTrLrrrES FOR AN ORDER APPROVING ) CeSE, AVU-G-14 -04
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 ldaho. The Applicant
requests that the proposed rates included in this Purchased Gas Cost Adjustment ("PGA") filing be
made effective on November 1,2014. If approved as filed, the Company's annual revenue will
decrease by approximately $1.6 million or about 2.1%. 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 offrce is 1411 East Mission Avenue, Spokane, Washington, and is qualified to do business in
the state of Idaho. Applicant maintains district offices 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
l4l I E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
II.
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
l4l I E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
III.
The Applicant is a public utility engaged in the distribution of natural gas in certain portions of
Northern Idaho, Eastern 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.
IV.
Twentieth Revision Sheet 150, which Applicant requests the Commission approve, is filed
herewith as Exhibit "A". Additionally, Sixteenth Revision Sheet 155, which Applicant requests the
Commission approve, is also filed herewith as Exhibit "A". Also included in Exhibit rrArr is a copy of
Twentieth Revision Sheet 150 and Sixteenth Revision Tariff Sheet 155 with the changes underlined
and a copy of Nineteenth Revision Sheet 150 and Fifteenth 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 "8" 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
from September 17,2014 through October 15,2014.
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 2014 through October 2015 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 summarizing the proposed changes reflected in this filing.
Sgfvice
General
Lg. General
Intemrptible
Sch.&
101
111
131
Commodity
Change
per therm
0.01160
0.01160
0.01r60
Demand
Change
per thm
(0.00022)
(0.00022)
0.00000
Total
Sch. 150
Change
0.01138
0.01r38
0.01160
Amortization
Change
per therm
(0.03071)
(0.03071)
0.001l9
Total Rate
Change
Pgr therm
(0.01e33)
(0.01e33)
0.01279
Overall
Percent
Change
-l.9lo/o
-2.49o/o
O.2Oo/"
x.
Commoditv Costs
As shown in the table above, the estimated WACOG change is an inuease of l.16 cents per
therm. The proposed WACOG, including the revenue conversion factor, is 38.5 cents per therm
compared to the present WACOG of 37 .4 cents per therm included in rates.
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
for the forthcoming PGA year (twelve months). Approximately 35%o of estimated annual load
requirements for the PGA year (November 2014 through October 2015) will be hedged at a fixed-price
derived from the Company's Plan. These volumes are comprised of: l) l3o/o of volumes hedged for a
term of one year or less, 2) 22% 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 $4.25 per
dekatherm ($0.425 per therm).
Available underground storage capacity at the Jackson Prairie Natural Gas Storage Facility
represents approximately 20%o of annual load requirements (36% of load requirements during the
December to March withdrawal period). The estimated WACOG for all storage volumes is $4.15 per
dekatherm. The Company utilizes its underground storage to capture seasonal price spreads
(differentials), improve the reliability of supply, increase operational flexibility and mitigate peak
demand price spikes.
The Company used a 30-day historical average of forward prices and supply basins (ending
August 18,2014) 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 45Yo of estimated
annual load requirements for the coming year. The annual weighted average price for these volumes is
$3.60 per dekatherm.
The winter of 2013-2014 was significantly colder than normal both in the western United States
and nationally. The colder than normal weather led to an increase in overall natural gas demand and a
heavy reliance on natural gas storage reserves. Natural gas storage both nationally and in the west
were drawn down well below their five year average balance. The cold weather and increased demand
increased wholesale natural gas prices both in the winter as well as in the summer as more natural gas
is required to replenish storage facilities. Storage may not be full by the coming winter, and this
storage imbalance may persist through the coming winter. While prices are currently forecast to
remain higher throughout the upcoming winter, natural gas prices in future winter periods are below
the upcoming winter. As a result, the market prices indicate that the storage imbalance issue is
temporary, and the long-term trend of lower priced gas should return.
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 decrease in the
overall demand rate. The expiration of short-term capacity release credits on Northwest Pipeline and
an increase in summer capacity on TCPL-Alberta Pipeline led to slightly higher demand costs,
however those are more than offset with higher projected usage to cover fixed demand costs. The
result is a slight demand rate decrease of $0.00022 per therm for Schedules 101 and I I l.
xt.
Schedule 155 / Amortization Rate Chanee
As shown in the table above, the proposed amortization rate change for Schedule l0l and
Schedule lll is a decrease of $0.03071 per therm. The current rate applicable to Schedule l0l and
Schedule I I I is $0.00015 per therm in the surcharge direction; the proposed rate is $0.03056 per therm
in the rebate direction. The reason for the decrease in the Schedule 155 amortization rate is due to
changes in the demand portion of the amortization rate, which include:
l. Colder than normal weather resulted in higher demand cost collections during the winter
months.
2. Effective April l, 2014, Avista entered into a new Deferred Exchange contract with a
counterparty whereby the Company receives natural gas at a specific point during one time
period (summer) and re-delivers that natural gas in a different time period (winter). The
Company charges a fixed per therm charge for this service. The net benefit provided to
customers from this new agreement in this PGA is approximately $394,000, and
3. As noted in the Company's Power Cost Adjustment filing (Case No. AVU-E-14-06), the
Company discovered an effor related to the allocation of natural gas transport costs between the
Company's power supply operations and the Company's natural gas distribution operations.
Details were provided in the December 2013 PCA Deferral Report filed with the Commission
on January 16, 2014. The net effect of this error is a decrease (i.e., a benefit to natural gas
customers) in the natural gas amortization deferral account of $487,554.
XII.
If approved as filed, the Company's annual revenue will decrease by approximately $1.6
million or about 2.lo/o effective November 1,2014. Residential or small commercial customers using
an average of 60 therms per month would see a decrease of $1.16 per month, or approximately 2.0o/o.
The present bill for 60 therms is $59.48 while the proposed bill is $58.32.
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 l, 2014, 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.
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 1,2014.
Dated at Spokane, Washington, this l2th day of Septemb er 2014.
AVISTA UTILITIES
BY
Vice President and Chief Counsel for
Regulatory and Governmental Affairs
VERIFICATION
STATE OF WASHINGTON )
)
CountyofSpokane )
David J. Meyer, being first duly swom 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 authorized;
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 12ft day of September2}l4,by David J. Meyer
Commission Expires:
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LIC in and for the State of
Washington, residing at Spokane.
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that I have served Avista Corporation dba Avista Utilities' Advice
filing ADV 14-01-G (Tariff IPUC No. 27 Natural Gas Service) by mailing a copy thereof,
postage prepaid to the following:
Jean D Jewell, Secretary Edward A. Finklea
ldaho Public Utilities Commission Northwest lndustrial Gas Users
472W. Washington Street 326 Fifth Street
Boise, lD 83720-5983 Lake Oswego, OR 97034
Chad Stokes Curt Hibbard
Cable Huston Benedict Haagensen & St. Joseph Regional Medical Center
Lloyd, LLP PO Box 816
1001 SW Sth, Suite 2000 Lewiston, ID 83501
Portland, OR 97204-1136
of September 2Ol4.
Patrick Ehrbar
Manager, State & Federal Regulation
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Case No. AVU-G -14-O 4
EXHIBIT O'A"
Proposed Tariff Sheets
September 12,2014
l.P.U.C. No.27
Twentieth Revision Sheet 150
Replacing
Nineteenth Revision Sheet 150 150
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
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 a9.286$ per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
38.5100 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 10.7760, 38.5100 49.286Q,
Schedules 111 and 112 10.7760, 38.5100 49.286i,
Schedules 131 and 132 0.0000 38.5100 38.5100
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.721i, 38.3120, 49.0330
Schedules 111 and 112 10.721i, 38.312i, 49.0330
Schedules 131 and 132 0.0006 38.312i, 38.3120,
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 September12,2014 Effective November 1,2014
lssued Avista
W Zll, /^ _Jelly O. Nonrood - Vice-President, State & Federal Regulation
Twentieth Revision Sheet 150
Replacing
|.P.U.C. No.27 Nineteenth Revision Sheet 150 150
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
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 49.286i, per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
38.5100 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 10.7760, 38.5100 49.2860,
Schedules 111 and 112 10.776Q, 38.5100 49.2860
Schedules 131 and 132 0.0000 38.5100 38.510d
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.7210, 38.312i, 49.0330
Schedules 111 and 112 10.7210, 38.3120, 49.0330
Schedules 131 and 132 0.0000 38.3120, 38.3120,
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 Seotember 12. 2014 Effective November 1. 2014
lssued Avistaby
By 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 a21414 per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
3735e# per therm.
(c) The rate for transportation under Schedule146 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 l0l
Schedules lll and 112
Schedules 131 and 132 0.0000 W
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules l0l
Schedules lll and 112
Schedules 131 and 132 0.0006 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.
Nineteenth Revision Sheet 150
Replacing
Revision Sheet 150 150
lssued by Avista
By Kelly O. Norwood - Vice-President, State & Federal Regulation
l.P.U.C. No.27
Sixteenth Revision Sheet 155
Canceling
Fifteenth Revision Sheet 155 155
AVISTA CORPOMTION
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 3.0566 per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0.9230 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 September12,2014 Effective November1,2014
byBy r .Kelly Nonrood, Vice President, State & Federal Regulation'ru/a'r,,J
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 3.0560 per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0.9230 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 September 12. 2014 Effective November 1. 2014
l.P.U.C. No.27
Sixteenth Revision Sheet 155
Canceling
Fifteenth Revision Sheet 155 155
lssued by
By
Avista Utilities
Kelly Norwood, Vice President, State & Federal Regulation
Fifteenth Revision Sheet 155
Canceling
Ssbetitute Feurteenth Revision Sheet 155l.P.U.C. No.27 155
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
in€rea€ed by 0Sa€S per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule'131 is to be decreased by
W 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 asdescribedinSchedule150-PurchaseGasCostAdjustmentM
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued luty+g#+e Effective Oeteger{-2o+g
QCI IA'Utilities
Kelly Nonntood, Vice President, State & Federal Regulation
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Case No. AVU-G-14-0 4
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
September 12,2014
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 (IPUC) in Boise, Idaho.
Twentieth Revision Sheet 150
Sixteenth Revision Sheet 155
canceling Nineteenth Revision Sheet 150
canceling Fifteenth Revision Sheet 155
Sixteenth 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 amual revenue decrease of approximately $1.6 million, or about2.lo/o.
This request is a Purchased Gas Cost Adjustment (PGA) that is 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 to Avista's local distribution system.
If the Company's request is approved, the average residential or small commercial customer
using 60 therms per month will see a decrease of $1.16 per month, or approximately 2.0Yo. The
present bill for 60 therms is $59.48 while the proposed bill is $58.32. Larger commercial
customers served under Schedules I I I can expect to see an average decrease of approximately
2.5%o. However, actual customer rate changes will vary based on therms consumed.
This filing requests an effective date of November l, 2014.
Avista's rate application is a proposal, subject to public review and a decision by the IPUC.
Copies of the application are available for public review atthe offices of the IPUC as well as on
the IPUC's homepage at www.puc.idaho.gov. Customers may subscribe to the Commission's
RSS feed (http://www.puc.idaho.gov/rssfeeds/rss.htm) to receive periodic updates via email about
the case. Written comments regarding Avista's application may be filed with the IPUC.
Copies of the proposed taxiff changes are also available for inspection in the Company's offices,itswebsite@),bycalling(509)495-4565orbywriting:
Avista Utilities
Attention: Manager, Rates & Tariffs
P.O.Box3727
Spokane, W A. 99220-3727
September 12,2014
i.i"0[:i"'i]i
20ll SIP l5 At{ 9: 09
AVISTA UTILITIES s;'.:,i,;.r j:;iil: l'l -UT lLlTltU ;,;;,:1,: :t": ii0;,1
Case No. AVU-G -14-0L
EXHIBIT "C"
Workpapers
September 12,2014
Iitle Description Pace Number
TARRIF CHANGE COMPARISONS
Revenue Chance Summarv'!A1 lhanee in Revenue as a result of filins 7
Rate Cha nee Summarv' !A1 lhange in rate, by schedule, Schedule 150 and 155 2
PGA COMPONENT CALCULATIONS
nput!A1 )emand Volumes and Customers lnputs 3
nput!A26 :ommoditv lnouts 4
noutlA88 )emand lnputs 5
nput!A185 \mortization lnouts 5
CommodiWlAl lommodity WACOG Calculation 7
DemandlAl )emand WACOG Calculation 8
Amortization!A1 \mortization WACOG Calculation 9
OTHER
Conversion Factor'!A1 levenue Conversion Factor 10
GRI Fundine GRI Funding 77
Pioeline Tariff Sheets' !A1 Iranscanada -Alberta 12
Westcoast Enersv lnc.13
Pipeline Tariff Sheets - Foothills Pioeline Ltd.L4
Northwest Pipeline Summary 15
Westcoast Enersv lnc.16
Northwest Pipeline Summary L7
Avista utilities
State of ldaho
Revenue Rate Change Sumamry
Based on 12 months November 1, 2014 - October 31, 2015
Schedrrle
une
No.
Rate
Chance
Revenue
lncr (Decrl
2 Rate schedule 101
3 Rate Schedule l11
4 Rate Schedule 112
5 Ratc Schedule 131
5 Rate schedule 132
55,0L2,923
23,L70,342
0
0
23,070
78,206,33s
55,0L2,923
23,r70,342 s
s
s
s
0
0
23,070
_18,206,33s_
5s,012,923 s
73,L70,342 50s0s
23,070 s0s0s0s0s0s
_18,206,33s_
0.01160 s
0.01150 s
0.01150 s
0.01160 s
(0.00022) s
(0.00022) s
(o.ooo22) I-s-s
-s
0.00119 s-s-s-5-S-s
(0.01e33) s
(0.01e33) s
0.01138 s
0.01279
0.01150
538,150
268,7-76
(12,103)
(5,097)
(40,;oe)
-
(5)
4
0.01160 s 268
-907,191
7
8
9
10 Rate Schedule 101
11 Rat. Schedule 111
12 Rate Schedule 112
13 Rate Schedule 131
14 Rate Schedule 132
15
16
17 Schedule 155 Amortization
18 RateSchedule 101
19 Rate Schedule 111
20 Rate Schedule 112
21 Rate schedule 131
22 Rate Schedule 132
23 customcr 1
24 Customer2
25 customer3
25 customer4
27 customers
28
29
30 Total chanEe 150 & 155
-l1rml(0.03071) s (1,68e,488)
(0.03071) s (711,s79)
- s (13,0s0)
T--ir/-60-"8-rEi
3l Ratc schedule 101
32 Rate schedute 111
33 Ratc schedule 112
34 Rate schedule 131
35 Rate schedule 132
36 Customer 1
37 Customer2
38 customer3
39 Customer4
40 Customers
4L
42
55,072,923
23,L70,342
0
0
23,070
0
0
0
0
0lotatchan8e@
(1,063,441)
(447,9001
i*
(46,709)
(5)
sSqs (13,0s0)S (1,570,834)
--_
$ (r,s70,834)
5
s
s
s
s
43 Rate Schedule 146 & Special Contracts
44
45 Total
45 % Change from Current Billed Revenue
Proposed Rates Total Billed % Chanse
schedule 101 (1,063,/t4U 5 55,569,742 -1.
schedule 111 (447,900) S 17,989,510
Schedule 112 0
Schedule 131 0
schedule 132 268 S 169,148
Tab: Revenue Change Summary Page: 2 of 21
sdii 136
ilritlsmnailrrtie*ffftn i&dr {lItft kEatE,fcrcl$rc,1la*t3
Present
,VACOG before revenue sensitive
tate schedule 101
late Schedule 111
late Schedule 112
late Schedule 131
late schedule 132
Proposed
,VACOG before revenue sensitive
late Schedule 101
iate schedule 111
tate schedule 112
late Schedule 131
late Schedule 132
Change
yVACOG before revenue sensitive
iate schedule 101
iate schedule 111
late Schedule 112
late Schedule 131
late schedule 132
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
50.10744 50.37164
s0.10744 50.37L64
s0.10744 s0.37154
S0.37154
S0.37164
s0.10721 s0.38312
s0.10721 50.38312
s0.10721 s0.38312
S0.38312
S0.38312
(so.ooo23) s0.01148(so.ooo23) s0.01148
(s0.ooo23) s0.01148
So.o1 148
S0.01148
50.47908
S0.47908
S0.47908
s0.37154
50.37164
s0.49033
s0.49033
s0.49033
50.38312
s0.38312
s0.01125
50.01125
s0.0112s
S0.01148
S0.01148
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
GRF: 1.005016
(so.ooo22) 50.01160(so.ooo22) 50.01160
(so.ooo22) 50.01160
So.o116o
s0.01150
s0.10798
s0.10798
S0.10798
GRF;
s0.10775
S0.10776
50.t0776
s0.37350
s0.373s0
s0.373s0
s0.373s0
50.373s0
1.00s165
s0.38s10
50.38s10
s0.38s10
s0.38s10
s0.38s10
s0.48148
S0.48148
S0.48148
s0.373s0
s0.373s0
S0.49286
s0.49286
s0.49286
s0.38s10
s0.38s10
S0.01138
S0.01138
S0.01138
s0.01150
s0.01150
Avista utilities
State of ldaho
Summary of Changes
1
2
3
4
5
5
7
8
9
10
11
t2
13
L4
15
L6
L7
18
19
20
27
22
23
24
25
26
27
28
29
30
31
32
33
34
35
35
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
(0.01933)
(0.01933)
0.01138
0.0t279
0.01160
.tl:\t\i:t'.t:\\.\li:tii.:;..:r.:.,i.tit'lllll;t:.",,:t:.tt.:.t.'. .SEhtlltlld $
li.*hffrt fcrtEir* 3t.l$Sa€:&iti ' um.xahrtff&,lgfstlr${dltr
Present
,VACOG before revenue sensitive
late Schedule 101
late schedule 111
late schedule 112
late Schedule 131
late Schedule 132
Proposed
ilACOG before revenue sensitive
tate schedule 101
late schedule 111
late Schedule 112
late Schedule 131
late Schedule 132
Change
,VACOG before revenue sensitive
late Schedule 101
late schedule 111
late Schedule 112
late schedule 131
late Schedule 132
Firm Sales
(Demand) (Commodity)
Amort Amort Total Amort Ra
s0.010s2 (s0.01037) s0.0001s
so.o10s2 (50.01037) So.ooo1s
(50.01037) (So.o1o37
(s0.02122) (so.oo919) (s0.03041,
(s0.02122) (s0.00e1e) (s0.030411
(S0 00919) (S0 00919,
(50.03174) So.oo118
(50.03174) So.oo118
s0.00118
(5o.o3os5l
(5o.o3os6l
So.oo1 18
Firm
(Demand)
Amort
GRF:
s0.01057
s0.010s7
Sales
(Commodity)
Amort
1.005016
(So.o1042)
(So.o1042)
(So.o1042)
Total Amort Rate
s0.0001s
So.oools
(so.o1o42)
GRF: 1.005155
(s0.02133) (s0.00e23) (s0.030s5)
(s0.02133) (s0.00s23) (s0.030s5)
(so.ooe23) (so.ooe23)
(s0.o3leo) s0.00119
(so.o319o) so.oo119
50.00119
(So,o3071
(s0.03071
So.oo119
Tab: Rate Change Summary
Check Total:
Page 3 of 21
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Avista Utilities
State of ldaho
Demand Cost Calculation (per Therm)
Line
No.Description Estimated Demand Expense
1
2
3
4
5
6
7
8
9
10
11
12
13
L4
15
16
L7
18
19
20
2L
22
23
(A)
Northwest Pipeline Corporation (NWP)
TCPL - Gas Transmission Northwest
Total Fixed Domestic Transportation Costs
TransCanada - NOVA System
TransCanada - Foothills Pipe Line Ltd.
Spectra - Westcoast Energy lnc
Total Fixed Canadian Transportation Costs
Total Demand Costs
Demand Volumes (Th)
Demand Rate
4,281,158
872,416
5,153,573
L,873,505
L,032,070
323,LLo
3,229,696
78,t83,26s
o.t072t
1.005165
Demand Rate without RCF S o.rozzr
Demand Rate with RCF S 0.10776
Tab: Demand Page: 9 of 21
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Line
No.
AVISTA UTILITIES
Revenue Conversion Factor
Idaho - Natural Gas System
TWELVE MONTHS ENDED DECEMBER 3I, 2OI3
Description
Revenues
Expenses:
Uncollectibles
Commission Fees
Idaho State Income Tax
Total Expenses
Net Operating Income Before FIT
Federal Income Tax@35%
REVENUE CONVERSION FACTOR
REVENUE GROSS UP:
I
2
J
4
5
6
7
8
Factor
1.000000
0.002608
0.002530
NA
0.00s 1
0.994862
0.348202
0.646660
1.005165
1.005016
(1/l -.00s 138)
Prior RCF
Tab: RCF (Conversion Factor)
Page: Ll.ofZt
Avista Utilities
State of ldaho
Voluntary GRI Funding
Previous Pipeline Rate (PerTherm)
Current Pipeline Rate (PerTherm)
Reduction in Pipeline Funding Rate (Per Therm)
Montly Rate (Daily Rate X 365 Days/l2 Months)
NWP Demand Billing Determinates
Estimated Transportation Volumes (Therms)
GRI Funding Shortfall
ldaho Percentage
Total ldaho GRI Funding Shortfall
Northwest Pipeline
TF-1 TF-1
Reservation Volumetric
s0.ooo86 so.ooo88
s0.00076 s0.0007s
Transcanada - GTN Pipeline Total
TF-1 TF.1
Reservation Volumetric
s0.00086 s0.00088
s0.00076 s0.0007s
s0.00010 s0.00013
s0.00316
558,085,000
s0,00010 s0.00013
s0.00316
0
s1,764,000
30.0L%
5o
30,57%
SoSo
30.0L% 30.57%
s14000 s3,000 sg,ooo s6,ooo s32,ooo
Set the GRI Funding at the 11/1/99 tevel.
Tab: GRI Page: 12 of 21
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Tab: Pipeline Tariff Sheets Page: 16 of 21
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Tab: Pipeline Tariff Sheets Page: 17 of 21
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Tab: Pipeline Tariff Sheets
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Tab: Pipeline Tariff Sheets Page: 19 of 21
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Tab: Pipeline Tariff Sheets Page: 20 of 21
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Page:2L of 27Tab: Pipeline Tariff Sheets
AVISTA UTILITIES
f \..i^'rrr."-l-11-l :11- i.... !.,..,. .. t.._
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Case No. AVU-G-14-0L
EXHIBIT "D"
Pipeline Tariffs
September 12,2014
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Second Revised Sheet No. 16
Superseding
f irst Revised Sheet No. 16
1.
RATE SCHEDULE TF-].
Firm Transportation
AVAILABILTTY
This Rate Schedule is availabl-e as provided herei-n and
lncorporates the General Terms and Conditlons to any party (herej-nafter
cal-Ied "Shipper") for the transportation of natural gas by Transporter
through Transporter's mainline transmission system under the following
conditions:
(a) Shlpper desires firm service and Transporter has available
capacity to render such firm service for Shipper. If at the time
service is requested under thls Rate Schedule, Transporter does
not have capacity to receive firm transportation gas at the
receipt point(s) requested for redelivery at the deliverypolnt(s) requested, Transporter shall offer to receive firm
transportation gas at other receipt point(s) where capacity may
be availab1e to enabfe redelivery at the delivery point(s)
requested;
(b) Transporter can conimence the service contempl-ated without
need for construction of any additional pipeline facilities.
except facilitj-es for whj-ch a facilities agreement has been
entered into between Transporter and Shlpper pursuant to Section
21, or 29 of the General Terms and Conditi-ons of this Tariff; and
(c) Shipper and Transporter have executed a Service Agreement
for service under this Rate Schedule.
As used in thj-s Rate Schedule, Transporter's mainlj-ne
transmissi-on system does not include Designated Lateral-s.
APPLICABILITY AND CHARACTER OF SERV]CE
2.L App1icabi1i-ty. This Rate Schedule sha1l apply to gas transported
by Transporter for Shlpper pursuant to the executed Servj-ce Agreement
for service under this Rate Schedule for TF-1 (Large Customer) and TF-1
(Sma1l Customer) service. The Service Agreement will specify the
customer category, i. e. , whether the Shipper j-s a Large Customer or
Sma1l Customer and, if the Shipper is an incremental expansion
customer, whether the Shipper 1s a Columbia Gorge Expanslon customer, a
15-Year Evergreen Expansion customer or a 25-Year Evergreen Expansion
customer.
Page 1 of90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No.
Second Revised Sheet No. 17
Superseding
First Revised Sheet No. 17
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
APPLICABILITY AND CHARACTER OF SERVICE (Continued)
(a) TF-1 (Large Customer): A11 rate provisi-ons contained inthis Rate Schedule apply to TF-1 (Large Customers).
(b) TF-1 (Sma11 Customer) : A TF-l- (Sma1l Customer) i-s anyplpeline or distribution company which elects Rate Schedule TF-1
(Sma1l Customer) service and whose aggregate Transportation
Contract Demand, as specified in its Service Agreement(s)
hereunder, is for 10,000 Dth per day or less. (A Shipperqualified to elect elther the TF-1 (Sma1l Customer) or TF-1
(Large Customer) service hereunder may change its election
permanently only i-n connection with the filing of a general
Section 4 rate case by Transporter. Transporter sha1l provide
such Shippers with an opportunity to make such an el-ection prior
to flJ-ing such rate appllcations. )
(c) Capacity Rel-ease Service is service initiated pursuant to
Section 22 of the General Terms and Condltions and an executed
Servlce Agreement for Rate Schedufe TP-1 (Large Customer)
service.
(d) Any Rate Schedule TF-1 (Small Customer) Shipper may convertall of its service temporarily to TF-1 (Large Customer) service
to participate in Transporter's Capacity Release Program without
amendj-ng j-ts service agreement, provided that such temporary
conversion sha1l be for a minimum term of twelve calendar months.
Notice of the j-ntent to so convert temporarily to TF-1 (Large
Customer) servj-ce must be gi-ven to Transporter efectronically
using the TF-1 (Sma11 Customer) temporary conversj-on electj-on
screen available in Northwest Passage on Transporter's DesignatedSite at least one (1) week prior to the beginning month for whlch
such conversion 1s to become effective. Shipper's temporary
conversion election constj-tutes agreement to the temporaryconversion. Any TF-1 (Sma11 Customer) Shipper particlpating in a
temporary conversion to TF-1 (Large Customer) service shaI1 pay
all rates and charges applicable to TF-1 (Large Customer) servi-ce
Page 2 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. l7-A
Superseding
First Revised Sheet No. l7-A
RATE SCHEDULE TF-1
Firm Transportation
(Continued)
2. APPLICABILITY AND CHARACTER OF SERVICE (Continued)
2.1 (d) (Continued)
during the term of such temporary conversion, includingreservation charges and surcharges applicable to such Shipper's
fu11 Transportation Contract Demand or such other rate to which
Transporter and Shipper mutually agree, reduced as applicable by
revenue credits applicable to Rel-eased Capacity. Any Rate
Schedule TF-1 (SmaII Customer) Shlpper which parti-cipates in sucha temporary conversion shall be entitled to return to Rate
Schedul-e TF-1 (SmaIl Customer) service upon expirati-on of the
term of the temporary conversion requested by such Shipper.
However, such Shipper shal-l- not be entitled to rel-ease its
capacity rlghts for a term which extends beyond the term of the
temporary conversion.
2.2 Transportation Components.
Schedule, which does not includeconsist of:
Transportation service under this Rateservice on Designated Laterals, sha11
(a) The receipt by Transporter for the account of Shipper of
Shipper's qas at the Receipt Point(s) specified in the executed
Service Agreement;
(b) The transportatlon of such gas through Transporterrspipellne system for the account of Shipper either dlrectly or by
displacement; and
Page 3 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. 18
Superseding
F'irst Revised Sheet No. 18
RATE SCHEDULE TF-].
Fj-rm Transportation (Continued)
2. APPLICABILITY AND CHARACTER OE SERVICE (Continued)
?
(c) The delivery of gas in thermally equivalent quantitles
after transportatlon (1ess any fuel use reimbursement furnishedin-kind in accordance with Sectlon 74 of the Generaf Terms and
Conditions) by Transporter to Shipper or for the account of
Shlpper 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 specified 1n its executed Service Agreement, subject to the
executed Service Agreement and the limitations of this Rate Schedule,
and is not subject to curtaifment or interruption except as expressly
provided in the General Terms and Condltions. Transportation service
rendered under this Rate Schedule in excess of Shipper's Transportation
Contract Demand is not firm.
MONTHLY RATE(S)
Each month, Shi-pper will pay Transporter for service rendered
under this Rate Schedule the sum of the amounts specified in this
Section 3, as appli-cab1e. Only those rate provisions contained j-n
Sections 3.2, 3,4, 3.5 and 3.7 apply to TF-1 (Small Customers).
3.1 Reservation Charge.
(a) Eor TF-1 (Large Customer) service, the Reservatj-on Charge
is the sum of the daily product of Shipperrs Transportation
Contract Demand as specified 1n the executed Service Agreement
and the Base Tariff Reservation Charge stated on Sheet No. 5 of
this Tarlff that applies to the customer category identified i-n
the Service Agreement. Unless specifically adjusted pursuant to
Section 3.5 herein, the Maximum Base Tariff Rate set forth on
Sheet No. 5 will apply.
For capacity release servj-ce, the Reservation Charge is the
sum of the daily product of the accepted reservation charge bid
Page 4 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Yolume No. I
Third Revised Sheet No. l8-A
Superseding
Second Revised Sheet No. 18-A
?
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
MONTHLY RATE (S) (Contj-nued)
price which was bid by a Replacement Shipper or a Prearranged
Replacement Shipper under the bidding procedures for capacity
releases set forth in Section 22 of the General- Terms and
Conditions and the Transportation Contract Demand acquired by the
Replacement Shipper or the Prearranged Replacement Shi-pper.
(b) Shipper wilJ- pay the Reservation Charges commencing with theprimary term begin date set forth in the Service Agreement.
3.2 Volumetric Charge: The sum of (a) and (b) below:
(a) An amount obtained by multiplying (f) the quantity of Dth
schedul-ed for delivery by Transporter to Shlpper after
transportation during the month, after reduction for fuel- use
reimbursement furni-shed in kind in accordance with the terms of
the executed Service Agreement and Section 14 of the Generaf
Terms and Conditions, by (ii) the TF-1 (Large Customer) or TP-1
(Smal-l 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 Tariff
Rate set forth on Sheet No. 5 sha11 apply.
(b) An amount obtained by multiplyinq (i) the quantity of Dth
scheduled for delivery by Transporter to Shipper aftertransportation during the month, after reduction for fuel use
reinlbursement furnished in kind 1n accordance with the terms of
the executed Service Agreement and Sectj-on 14 of the General
Terms and Conditions, by (ii) the ACA component as referenced in
footnote 2 on Sheet No. 5-A of this Tariff. This charge sha1l be
subject to adjustment in accordance wj-th Section 16 of the
General Terms and Conditions.
3.3 Volumetric Refease Charges: For Capacity Refease service pursuantto Section 22 of the General Terms and Condltions which is provided
under a volumetric bld rate the sum of (a), (b) and, if applicable, (c)
befow:
(a) The amount obtained by multiplying (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 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No.
Second Revised Sheet No. 19
Superseding
First Revised Sheet No. 19
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
3. MONTHLY RATE(S) (Continued)
reduction for fuel use reimbursement furnished i-n kind in
accordance wlth the terms of the executed Servj-ce Agreement and
Sectj-on 14 of the General Terms and Conditions, by (if) the
accepted volumetric bid made by a Replacement Shipper or a
Prearranged Replacement Shipper and by (iii) the Rate Schedule
TF-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 Shlpper has specified a minimum averaqeload factor volumetric commitment, an amount equal to the accepted
vol-umetric bid times the difference, if positive, between (i) the
specified average load factor times Replacement Shipper's or
Prearranged Replacement Shipper's Transportatlon Contract Demand
times the number of days the Transportatj-on Servj-ce Agreement is
in effect during the month, and (ii) the quantity of Dth delivered
by Transporter to Replacement Shipper or Prearranged RepJ-acement
Shipper under the subject Service Agreement during the month.
3.4 Additional Facj-lity Reservatlon Surcharge: A Shipper who
contracts for Columbia Gorge Expansj-on Project capacity will pay thefacillty reservation surcharge set forth in the footnotes to Sheet No. 5of this Tariff and such surcharge will be in addltion to all otherappllcable rates stated in this Section 3. The facillty reservation
surcharge was derived based on Transportation Contract Demand and the
cost of service attributabl-e to the Columbia Gorge Expansion Project
incremental facil-ities and such derivation w111 remain in place untif
such time as a different alfocation procedure 1s specifj-ed by Commission
order. The monthly facilities reservation surcharge wiIl be the sum of
the daily product of Shipper's Transportation Contract Demand asspecified in the executed Service Agreement and the applicable facility
reservation surcharge for the Columbia Gorge Expansion Projectfacilities specified in the Footnotes to Sheet No. 5 of this Tariff.
Page 6 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Second Revised Sheet No. 19-A
Superseding
First Revised Sheet No. 19-A
RATE SCHEDULE TF-1
Firm Transportatlon
( Continued)
MONTHLY RATE(S) (Continued)
3.5 Discounted Recourse Rates i
(a) Transporter reserves the right to discount at any time the
Recourse Rates for any indlvidual Shipper under any service
agreement without discounting any other Recourse Rates for that or
another Shipper; provided, however, that such discounted Recourse
Rates will not be less than the minimum base rates set forth on
Sheet No. 5 of this Tariff, or any superseding tariff. Such
discounted Recourse Rates may apply to specifj-c volumes of gas
(such as volumes above or below a certain 1eve1 or all volumes if
volumes exceed a certain l-evel-), volumes of gas transported during
specific time periods, and vol-umes of gas transported fromspecific receipt points and/or to specific delivery points, withinspecific corridors, or within other defined geographical areas.If Transporter dlscounts any Recourse Rates to any Shlpper,
Transporter will file with the Commission any required reportsreflectlng such discounts.
Page 7 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No.
Third
Second
Revised Sheet No.20
Superseding
Revised Sheet No. 20
3.
RATE SCHEDULE TF-1
Firm Transportation
( Continued )
MONTHLY RATE(S) (Continued)
3.6 Charges for Capaclty Release Service: The rates for capacity
refease service are set forth in Sheet No. 5. See Section 22 of the
Generaf Terms and Conditions for information about rates for capacity
release service, including information about acceptable bids. In the
event of a base tariff maximum and/or mj-nimum rate change, wherej-n the
Replacement Shipper has not agreed to pay the Maxlmum Base Tarlff Rate
or a percentage of the Maximum Base Tariff Rate (as it may change from
tj-me-to-time), the Replacement Shipper will be obligated to pay:
(a) for capacity release transactions that are subject to the
Maximum Base Tariff Rate pursuant to FERC regulati-ons: the lesser
of the awarded bid rate and the new Maximum Base Tariff Rate
unless the awarded bid rate is less than the new mj-nimum rate, in
which case the new minimum rate will apply for the remaining term
of the release,
(b) for capacity release transactions that are not subject tothe Maximum Base Tariff Rate pursuant to EERC regulations: thegreater of the minimum base tariff rate and the awarded bid rate
for the remaining term of the release.
3.'7 Negotiated Rates: Notwithstandlng the general provisions of this
Section 3, if Transporter and Shipper mutually agree to Negotiated
Rates for service hereunder, such Negotiated Rates will apply in lieu
of the otherwise applicable rates identified i-n this Section 3.
3.8 Facilities Charge: If Transporter and Shlpper enter into afacil-ities agreement pursuant to Section 2L or 29 of the General Terms
and Conditions for Transporter to construct facllltles and for Shipperto pay a faciliti-es charge, the facilities charge will be set forth onExhibit C to an executed Service Agreement.
Page 8 of 90
Northwest Pipeline LLC
FERC Gas Tariff
tr'ifth Revised Volume No. I
First Revised Sheet No. 20-A
Superseding
Substitute Original Sheet No. 20-A
4.
q.
RATE SCHEDULE TE-1
Firm Transportation
( Continued)
MINIMUM MONTHLY BILL
Unless Transporter and Shipper mutually aqree otherwise, the Minimum
Monthly Bill will consist of the Reservation Charge speclfied in
Section 3.1 of this Rate Schedule, as applicable.
TRANSPORTATION CONTRACT DEMAND
The Transportation Contract Demand is the maximum quantity of Gas,
expressed in Dth, that Transporter is obligated to receive (exclusive
of fuel reimbursement furnished in-klnd pursuant to Section 14 of the
General Terms and Conditions), transport and del-iver for Shipper on a
Page 9 of 90
Northwest Pipeline LLC
F''ERC Gas Tariff
Fifth Revised Volume No. I
Second Revised Sheet No. 21
Superseding
First Revised Sheet No.21
RATE SCHEDULE TF-1
Flrm Transportation (Continued)
5. TRANSPORTATION CONTRACT DEMAND (Continued)
A
firm basis on any one Gas Day, as specified 1n an executed Service
Agreement for service under this Rate Schedule. Transporter's service
obligation is limited to Shipper's Transportation Contract Demand as
adjusted for any released capacity pursuant to Section 22 of |uhe
General Terms and Conditions.
As long as the Transportation Contract Demand, as adjusted for any
capacity releases, is not exceeded, Transporter shaff be obligated to
receive up to Shipperfs Maximum Daily Quantity (MDQ) at each Prlmary
Receipt Point and to deliver up to Transporterrs Maximum Daily Delivery
Obllgation (MDDO) at each Primary Delivery Point at pressures at least
as great as the pressures specj-fied in Shipperrs TE-1 Service
Agreement, on a firm basis, as such MDQ and MDDO are adjusted for any
released capacity pursuant to Section 22 of the Generaf Terms and
Conditions.
The aggregate MDQ at the Primary Receipt Polnts, as specified in
a Servj-ce Agreement for service under this Rate Schedule, must equalthe Transportation Contract Demand. The aggregate MDDO at the Prj-mary
Delivery Poj-nts, as specified in a Service Agreement for servi-ce underthis Rate Schedul-e, 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-exlsting conjunctive nomj-nation 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 will- schedule such quantities in
accordance with the priority of service and curtailment policy
delineated in Section 12 of the General Terms and Conditions.
Page 10 of90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Second Revised Sheet No. 21-A
Superseding
First Revised Sheet No.21-A
RATE SCHEDULE TF-1
Firm Transportatlon (Continued)
6.SCHEDULED OVERRUN TRANSPORTATION (Continued)
For Scheduled Quantltles in excess of Shipperrs Transportation
Contract Demand, Shipper sha1l pay for the excess gas transportatlon 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 quantlty of Dth in
excess of Transportation Contract Demand by (ii) the maximum base
scheduled overrun transportatlon 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 multiplylng (i) the quantity of Dth in
excess of Transportation Contract Demand by (ii) the ACA
component as referenced in footnote 2 on Sheet No. 5-A of thisTariff. Thls charge shall be subject to adjustment in accordance
with 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 transportatlon
rate, Shlpper may, when nominating, electronically select an
option that will automatically increase (by a stated dol-l-ar
increment per dth) such rate up to the rate that will increasethe 11kelj-hood of such quantities being scheduled pursuant to
Section 12 of the General Terms and Conditlons.
6.2 The fuef reimbursement provided for in Section 7 of thls Rate
Schedule.
Page 11 of90
Northwest Pipeline LLL
FERC Gas Tariff First Revised Sheet No.22
X'ifth Revised Volume No. I Superseding
Substitute Original Sheet No. 22
RATE SCHEDULE TF-1
Firm Transportation (Continued)
.1. FUEL GAS REIMBURSEMENT AND BTU BALANCING
Refer to Section 14 of the General Terms and Conditions.
8. SHIPPERIS ARRANGEMENTS PRIOR TO RECEIPT AND AFTER DEL]VERY
Refer to Section 14 of the General Terms and Condltions.
9. GENERAL TERMS AND CONDIT]ONS
The General Terms and Conditions contained in this Tariff, except
as modified in the executed Service Agreement, are applicable to thls
Rate Schedule and are hereby made a part hereof.
10. RESERVATTON CHARGE ADJUSTMENTS
10.1 Eliqibility. Any Shipper receiving firm transportation service
under this Rate Schedule may be eligible for reservation charge
adjustments if Transporter fa11s to provide primary flrm transportation
due to scheduled or unscheduled maintenance, force majeure, or theUnavailability of Transporter's Facifities.
10.2 Definitions. For purposes of this Section 10 on1y. the followingdefinitions apply:
Annual Defj-ciency Volume: The Annual Defj-ciency Volume for any
Constraint Point is the sum of the Deficiency Volumes at that
Constraint Point for all Deficiency Periods during a calendar
year.
Annual Exemption Volume: The Annual Exemptlon Volume for any
Constraint Point is the l-esser of (1) the Constraint Point Design
Capaci-ty or (2) the aggregate Constraint Point Firm Rights, tj-mes
365 (or 366 days for leap years), multiplied by three percent
(38).
Page 12 of90
Northwest Pipeline LLC
['ERC Gas Tariff
Fifth Revised Volume No.
10.
First Revised Sheet No.22-A
Superseding
Substitute Original Sheet No.22-A
RATE SCHEDULE TF-1
Firm 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 malntenance, 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 Point Actual Capacity: Physical capacity at a
Constraint Point which is available on any day.
Constraint Point Desi-gn Capacity: Physical deslgn capacity at a
Constraj-nt Point when al-I facilities are fuIIy functional under
reasonably representatj-ve operating assumptions.
Constraint Poj-nt Firm Rights: The rights of a Shipper under Rate
Schedule TF-1 to receive firm service through a Constraint Point,
based on (1) primary receipt and delivery point rights and (2)
corridor rights where primary receipt and/or dellvery points
establish a call on the relevant capacity.
Deficiency Period: A Deficiency Period begins on the day when
aggregate nominations uslng Constraint Point Firm Rights exceed
Constraj-nt Point Actuaf Capacity and Transporter is unable to
schedule otherwise acceptable nominations due to scheduled or
unscheduled maintenance, force majeure, or the Unavailability of
Transporter's Facj-Iities. A Deflclency Period continues until the
earlier of (1) the day when the Constraj-nt Point Actual Capacity
1s restored to the level of the Constraint Point Design Capacity
or (2) the day when Transporter is abfe to schedule all otherwise
acceptable nominations with applicable Constraint Point Firm
Rights. A Deficiency Perlod may be a Declared Entitlement Period,
subject to the provisions of Section 14.6 of the General Terms and
Conditions.
Page 13 of90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Third Revised Sheet No.22-B
Superseding
Second Revised Sheet No.22-B
10
RATE SCHEDULE TF-1
Firm Transportation (Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
Deflciency Volume: The quantj-ty derived from subtracting the
Constraint Point Actual Capacity from the lesser of (1) the
Constraint Point Design Capacity or (21 the aggregate Constraint
Point Eirm Rights.
Excess Deficiency Volume: The Excess Deflciency Volume for any
Constraint Point 1s the amount by which the Annual Deficiency
Volume for a Constraj-nt Point exceeds the Annual Exemption Volume
for that Constraint Polnt.
Unavallability of Transporter's Facilities: Where Transporter's
facifities that have been certificated, constructed, and placed
into service cannot be fulIy utilized for their lntended operation
and use for reasons other than scheduled or unscheduled
maintenance or force majeure.
10.3 Determinatj-on of Adjustments. Pursuant to extensive negotiations
and the settlement reached between Transporter and Shlppers as
identified in Docket No. RP99-81-000, and approved by the Commission on
November 6, 1998,85 FERC 5[ 61,195, reservation adjustments wiII be
cafculated as follows:
(a) On the first day of any Deficiency Period, Transporter wilf
post to its Designated Site the daily Deficiency Volume for the
affected Constraint Point, the Constraint Point Design Capacity,
the Constraint Point Actuaf Capacity, and the estimated duration
of the Deficiency Period. Such information may be revised as
appllcable during the Deficlency Period.
(b) At least 24 hours prior to the end of any Deflciency
Period, Transporter wifL notify affected Shippers via a posting
on Transporter's Designated Site, and, if specified by Shipper on
the Busj-ness Associate Information form, via an Internet E-mai1
or fax to the Shipper, of the date on which Transporter expects
to restore the Constraint Point Design Capacity or to be able to
schedule all nominations with Constraj-nt Point Firm Rights. If
Transporter 1s able to restore the Constralnt Point Design
Capacity or is abl-e to scheduLe such nominations, the Deficj-ency
Period will be deemed to have ended as specj-fied by Transporter.
Otherwise, the Deficiency Period wilf continue until Constraint
Point Design Capacity is restored or aggregate nominations with
Constraint Point Elrm Rlghts can be scheduled.
Page 14 of 90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
First Revised Sheet No. 22-C
Superseding
Substitute Original Sheet No. 22C
10
RATE SCHEDULE TF-l
Firm Transportation (Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
(c) At the end of each calendar year, Transporter wil-l post the
Annual Deficiency Volume and the Annual Exemptlon Volume for each
affected Constraint Point. Transporter will then compare the
Annual Deficiency Volume for each affected Constraint Point to
the Annual- Exemption Volume for that Constraint Point. If there
is an Excess Deficiency Vo1ume for any Constraint Point,
Transporter will allocate such Excess Deficiency Volume pro rata
to the affected Shippers, based on Constraint Point Firm Rights
during the Deficiency Period(s). Each Shipper's allocation will
be the sum of its applicable Constraint Point Eirm Rights for all
Deficiency Periods dj-vided by the sum of the applicable
Constralnt Point Firm Rights of all- Shlppers for those Deficiency
Periods, multiplied by the Excess Defj-ciency Volume for a
Constraint Point.
(d) Transporter w111 calculate reservation charge adjustments
under each Service Agreement by multlplying a Shipper's allocated
share of the Excess Deficiency Volume for each Constraint Point
by the weighted averaqe Base Tariff Reservatlon Charge paid under
such Service Agreement for such Constralnt Polnt for the
Deflciency Periods during whj-ch the Service Agreement was 1n
effect.
10.4 Palment. A11 reservatlon charge adjustments will be issued or
refunds paid within 90 days from the end of the applicable calendar
year.
Page 15of90
Northwest Pipeline LLL
FERC Gas Tariff
Fifth Revised Volume No. I
10.
First Revised Sheet No. 22-C
Superseding
Substitute Original Sheet No. 22C
RATE SCHEDULE TF-1
Firm Transportation (Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
(c) At the end of each calendar year, Transporter will 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 Constraint Point to
the Annual Exemptj-on Volume for that Constraj-nt Point. If there
is an Excess Deficiency Volume for any Constraint Polnt,
Transporter will allocate such Excess Deflciency Volume pro rata
to the affected Shippers, based on Constraint Point Firm Rights
during the Deficiency Period(s). Each Shipper's allocation wj-l-1
be the sum of its applicable Constraint Point Firm Rights for all
Deficiency Periods divlded by the sum of the applicable
Constraint Point Flrm Rlghts of aI1 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 average Base Tarj-ff Reservation Charge paid under
such Service Agreement for such Constralnt Point for the
Deficj-ency Periods durlng which the Service Agreement was in
effect.
10.4 Payment. A11 reservation charge adjustments will be issued or
refunds paid wi-thin 90 days from the end of the applicable calendar
Page '16 of 90
Northwest Pipeline LLL
FERC Gas Tariff
Fifth Revised Volume No.
First Revised Sheet No.23
Superseding
Substitute Original Sheet No. 23
10.
RATE SCHEDULE TF-1
Firm Transportation
( Continued)
RESERVATION CHARGE ADJUSTMENTS (Continued)
10.5 Sole Remedy. Reservation charge adjustments pursuant to this
Sectlon 10 are Shipper's sole remedy for damages relating to
Transporter's failure to provide primary fj-rm transportation service
under Rate Schedule TF-1, unless such damages result from the negligence
or wil-l-fu1 mj-sconduct of Transporter.
RECETPT AND DELTVERY POINT FLEX]BILITY
11.1 Permanent Changes to Primary Receipt and Delivery Points.
Subject to the avallabifity provisions of this Rate Schedule, any
Shipper may permanently change primary receipt. or delivery poi-nts by
amendi-ng Exhlbit A of the Service Agreement.
1l-.2 Use of Alternate Receipt and Delivery Points on a Temporary
Basis .
(a) All TF-1 Shippers may use any physical receipt or delivery
point without amending Exhibit A of the Service Agreement. Such
points w111 be avail-able for the receipt or del-ivery of gas on a
firm basis, in accordance with the scheduling priorities
delineated in Sectj-orr t2 of the General- Terms and Conditions.
(b) Transporter shaff schedule service at alternate receipt anddellvery points on a dai-1y basis pursuant to Section l-4 of the
General Terms and Conditlons.
(c) The scheduling of service at alternate recelpt or deliverypolnts under a Service Agreement w111 not result in the loss of
firm contract rights to a Shlpper's primary receipt or deliverypoints as specified in the Shipper's Service Agreement.
11.3 Procedures for Requesting Permanent Receipt and Defivery Point
Changes. Any Shipper who wishes to amend the primary receipt ordelivery points, or the associated Maximum Daj-Iy Quantity or MaximumDaily Delivery Obligation named in Exhibit A of its Service Agreement,will electronically request and execute on Transporter's Designated Site
an amendment to the applicable Service Agreement
t1
Page 17of90
Northwest Pipeline LLL
FERC Gas Tariff
Fifth Revised Volume No.
Second Revised Sheet No. 24
Superseding
First Revised Sheet No. 24
11
RATE SCHEDULE TF-1
Ej-rm Transportation
( Continued )
RECEIPT AND DELIVERY POINT FLEXIBTLITY (Continued)
by 1:00 p.m. Central Clock Time (12:00 noon Mountain Clock 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 prlor to the commencement of service,
unless otherwise agreed to by the parties. If Transporter determines
that a receipt or dellvery point change request can be honored, the
amendment to the Servj-ce Agreement wil-I be executed by Transporter.
The change will become effective on the later of the requestedeffective date or the date executed by Transporter, provided that such
date sha1l not exceed fifteen days from the date of receipt of the
amendment by Transporter. Notice of the resulting changes 1n availabl-ereceipt or delivery polnt capacity will be posted to Transporterrs
Designated Site at least one (1) buslness day prior to implementationof such change.
Firm recei-pt and delivery point and associ-ated mainline capacity w111
be posted to Transporter's Designated Site pursuant to Section 25.2 ofthe Generaf Terms and Conditions and will be avaj-l-able for permanent
receipt and/or dellvery point changes only pursuant to the procedures
outlined in Section 25 of the General Terms and Conditions.
LL.4 Transporter's Maximum Service Obligation. The total- volumes
nominated for service on any day for all receipt or delivery points
must not exceed Transportatj-on Contract Demand under a Shipper's firm
Service Agreement, except as otherwise provided in Section 6 of this
Rate Schedule.
CONTRACT TERM EXTENSIONS
L2.7 Standard Unilateral Evergreen Provj-slon. If Transporter and
Shj-pper aqree to j-nclude a standard unilateraf evergreen provision as
indicated on Exhibit A of a long-term Service Agreement, the following
conditions will apply:
(a) The established rollover period will be one year.
72
Page 18 of90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
11.
First Revised Sheet No. 23
Superseding
Substitute Original Sheet No. 23
RATE SCHEDULE TF-1
Eirm Transportation
(Continued)
l-0. RESERVATION CHARGE ADJUSTMENTS (Continued)
10.5 Sole Remedy. Reservation charge adjustments pursuant to thls
Section l-0 are Shipper's sofe remedy for damages relating to
Transporter's failure to provlde primary firm transportati-on service
under Rate Schedule TF-1, unless such damages resufL from the negligence
or wi11fu1 misconduct of Transporter.
RECE]PT AND DELIVERY POINT FLEX]BILITY
11.1 Permanent Changes to Primary Receipt and Delivery Points.
Subject to the avai1ab111ty provisions of this Rate Schedu1e, any
Shipper may permanently change primary recelpt or delj-very points by
amending Exhj-blt A of the Service Agreement.
1.1".2 Use of Alternate Recelpt and Del-j-very Points on a Temporary
Basis .
(a) All TF-1 Shippers may use any physlcal receipt or deliverypoint without amending Exhibit A of the Service Agreement. Suchpoints wilf be available for the receipt or delivery of gas on afirm basis, in accordance with the scheduling prlorities
delineated 1n Sectj-on 1-2 of the General Terms and Conditions.
(b) Transporter shal-l schedule service at alternate receipt anddelivery points on a daily basls pursuant to Section 14 of the
General Terms and Conditions.
(c) The scheduling of servj-ce at alternate receipt or deliverypoints under a Service Agreement will not result in the loss offirm contract rights to a Shlpperrs primary receipt or deliverypoints as specified in the Shipper's Service Agreement.
11.3 Procedures for Requesting Permanent Receipt and Delivery Polnt
Changes. Any Shipper who wishes to amend the primary receipt ordelivery points, or the associated Maximum Daily Quantity or MaximumDaily Delivery Obligation named in Exhibit A of its Servlce Agreement,
wil-l- electronically request and execute on Transporter's Designated Site
an amendment to the applicable Service Agreement
Page 19of90
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No.
Second
First
Revised Sheet No. 24
Superseding
Revised Sheet No.24
11
RATE SCHEDULE TF-1
Flrm Transportatlon
( Continued)
RECEIPT AND DELIVERY POINT ELEXTBILITY (Continued)
by 1:00 p.m. Central Clock Tj-me (12:00 noon Mountain Clock Time) four(4) business days prior to the first of the month for which the changeis desired, or for changes to occur during a month, after the flrst of
the month, two (2) business days prior to the commencement of service,
unless otherwise agreed to by the parties. 1f Transporter determinesthat a receipt or dellvery point change request can be honored, the
amendment to the Service Agreement will be executed by Transporter.
The change wil-1 become effective on the l-ater of the requested
effective date or the date executed by Transporter, provided that such
date shal1 not exceed fifteen days from the date of receipt of the
amendment by Transporter. Notice of the resulting changes in available
receipt or delivery point capacity will- be posted to Transporter's
Desj-gnated Site at least one (1) business day prior to implementatlon
of such change.
Firm receipt and delivery polnt and associated mainline capacity will
be posted to Transporter's Designated Site pursuant to Section 25.2 ofthe General Terms and Conditions and wifl be availabfe for permanent
receipt and/or delivery point changes only pursuant to the procedures
outlined in Section 25 of the General Terms and Conditions.
1L.4 Transporter's Maximum Service Obligation. The total volumes
nominated for service on any day for all recej-pt or delivery points
must not exceed Transportation Contract Demand under a Shipper's firm
Service Agreement, except as otherwise provided in Section 6 of this
Rate Schedule.
CONTRACT TERM EXTENS]ONS
L2.L Standard Unilateral Evergreen Provision. If Transporter and
Shipper agree to incfude a standard unj-1atera1 everqreen provision asindicated on Exhibit A of a long-term Service Agreement, the following
conditions will apply:
(a) The established rollover period will be one year.
72
Page 20 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April26,2012
Effective: May 28,2012
PART 3
MAPS
v.3.0.0 Superseding v.2.0.0
Docket No. RPI 2-639-000
Accepted: May 24,2012
Page 21 of90
System Map
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
STATEMENT OF EFFECTIVE
TRANSPORTATION
PART 4.I
4.1 - Statement of Rates
FTS-I and LFS-I Rates
v.l 1.0.0 Superseding v.10.0.0
RATES AND CHARGES FOR
OF NATURAL GAS
Rate Schedules FTS-I and LFS-1
RESERVATIONDAILY DAILY
MILEAGE (a) NON-MILEAGE (b) DELIVERY (c) FUEL (d)(Dth-MrLE) (Dth) (Dth-MILE) (Drh-MILE)
Max. Min. Max. Min. Max. Min. Max. Min.
0.000498 0.000000 0.039216 0.000000 0.000016 0.000016 0.0050% 0.0000%
(e) 0.000000 (e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
BASE
STF (e)
SI-JRCHARGES
ACA (k)
lssued: November 18, 2013
Effective: December 19, 2013
EXTENSION CHARGES
MEDFORD
E-r (f) 0.003290 0.000000 0.005498 0.000000
E-2 (hXD 0.002972 0.000000
(Diamond l)
E-2 (hxl) 0.001166 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (D 0.001412 0.000000
oVERRLTN CHARGE (i)
0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.001420 0.000000 0.000000 0.000000
(k)(k)
Docket No. RPl4- I 80-000
Accepted: December 12, 2013
Page 22 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.2
4.2 - Statement of Rates
ITS-I 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
BASE
MILEAGE (n)
(Dth-Mile)
Max. Min.
(e) 0.000000
NON-MILEAGE (o) DELIVERY (c) FLJEL (d)(Dth) (Dth-Mile) (Dth-Mile)
Max. Min. Max. Min. Max. Min.
(e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-l (Medford) (f)
0.003290 0.000000
COYOTE SPRINGS
E-3 (Coyote Springs) (i)
0.001412 0.000000
SURCHARGES
ACA (k)
0.005498 0.000000 0.000026 0.000026
0.001420 0.000000 0.000000 0.000000
(k)(k)
Issued: July 25,2013
Effective: October l, 2013
Docket No. RPl 3- l 1 00-000
Accepted: September 17, 2013
Page 23 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v.7.0.0 Superseding v.6.0.0
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 0.0000Yoper Dth per mile. The fuel and line loss percentage surcharge is 0.0002%
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 Intemet website under
"Informational Postings. "
(e) Seasonal recourse rates apply to short-term firm (STF) service under Rate Schedule FTS-l
(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 2Peak I Peak 0 PeakMos. Mos. Mos. Mo. Mos.
Peak NM Res. $0.054902 $0.054902 $0.054902 $0.0s4902 $0.039216
Peak Mi. Res. $0.000697 $0.000697 $0.000697 $0.000697 $0.000498
Issued: November 22,2013 Docket No. RPl4-202-000
Effective: January 1,2014 Accepted: Decemberir"Z?lrr],
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Off-Pk NM Res.
Off-Pk Mi. Res.
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v.7.0.0 Superseding v.6.0.0
$0.033987 $0.036079 $0.037790 $0.039216
$0.000432 $0.0004s8 $0.000480 $0.000498
"Peak Months" may be found on GTN's Internet website
By March I of each year, GTN will post the Peak Months
period beginning June I of the same year.
Docket No. RPI 4-202-000
Accepted: December 17,2013
Page 25 of 90
$0.031373
$0.000399
Months currently designated as
under "Informational Postings. "
for the upcoming twelve-month
(D
(e)
(h)
Applicable to frm service on GTN's Medford Extension.
Reserved for Future Use.
Applies to Diamond Energy service, which corlmences 1998. Rate is negotiated
reservation charge of $0.002972 per Dth per day for first 45,000 Dth/d and $0.001166 per
Dth per day for the second 45,000 Dth/d. Revenues will be applied to annual revenue
requirement on the Medford Extension.
(r) Applicable to firm service on GTN's Coyote Springs Extension.
0) The Ovemrn Charge shall be equal to the rates and charges set forth for interruptible service
under Rate Schedule ITS-1.
(k) In accordance with Section 6.22 of the Transportation General Terms and Conditions ofthis
FERC Gas Tariff, Fourth Revised Volume No. 1-A, all Transportation services that involve
the physical movement of gas shall pay an ACA unit adjustment. The currently effective
ACA unit adjustment as published on the Commission's website (www.ferc.gov) is
incorporated herein by reference. This adjustment shall be in addition to the Base Tariff
Rate(s) specified above.
(l) Daily reservation charges will be reset for leap years.
(m) Reserved.
(n) The Rate Schedule ITS-I Mileage Component shall be applied per pipeline mile to gas
transported by GTN based on the distance of gas transported. Consult GTN's system map
in Section 3 for receipt and delivery point and milepost designations.
(o) The Rate Schedule ITS-I Non-Mileage Component shall be applied per Dth of gas
transported by GTN for immediate delivery to the facilities of another entity or an extension
facility.
Issued: November 22, 2013
Effective: January l, 2014
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
lssued: May 26,2011
Effective: Jlune27,20ll
PART 4.4
4.4 - Statement of Rates
Reserved For Future Use
v.3.0.0 Superseding v.2.0.0
RESERVED FOR FUTURE USE
Docket No. RPI l-2132-000
Accepted: June 10,2011
Page 26 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: December 14, 20ll
Effective: January l, 2012
PART 4.5
4.5 - Statement of Rates
Parking and Authorized Imbalance Services
v.3.0.0 Superseding v.2.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS FOR
Parking and Authorized Imbalance Services
($/otn;
RATE SCHEDULE
AND TYPE OF CHARGE
PS-l Parking Service:
AIS-I Authorized Imbalance Service:
Notes:
BASE TARIFF RATE
MINIMUM MAXIMUM
0.0
0.0
0.2781241d
0.2781241d
Docket No. RPl2-238-000
Accepted: December 29, 20ll
Page 27 of 90
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. /1
TERM OF RATE
CONTRACT SCHEDULE
tyt/01- FTS-I
t0/3U2s
PRIMARY
RECEIPT
DTH/D POINT
20,000 Medford
PRIMARY
DELIVERY RATE
POINT 1213
Medford Ext. 17
Meter
Kingsgate ll0Malin
Kingsgate l4
Issued: January 6,2012
Effective: January l, 2012
04/U03 - FTS-I 20,000
ll0
0U0y12 - FTS-I 50,000
0sl3v14
Malin
Docket No. RPl2-254-001
Accepted: January 30, 2012
Page 28 of g0
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: July 25,2013
Effective: October 1,2013
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. RPl 3- l 1 00-000
Accepted: September 17,2013
Page 29 of 90
l3
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
ll This contract does not deviate in any material aspect from the Form of Service Agrcement
in this Tariff.
12 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 Index) Spot Gas Price for the specified point.
The Maximum LTF Settlement Rate, as filed on October 31,2007, inthe 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-10526 beyond the "Moratorium," as that term is defined in Anicle V.A.l
of the Settlement.
l5 Reserved
16 Reserved
17 The Reservation charge shall be equal to the rate set forth in GTN's FERC Gas Tariff
identified as FTS-I E-2 (WWP), or its successor, multiplied by the appropriate Effective
Period Percentage as shown in the following table.
Effective Period Percentagett/U0r-r0/31/02 75%tur/02-t0/3y03 80%tr/U03-r0/31/04 85%IUU04-1013U05 90%tuy05-10/3y06 95%t1/U06-t0l3t/2s 100%
/4
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
/12 Reserved
Issued: July 25,2013
Effective: October 1,2013
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. RPl 3- l 1 00-000
Accepted: September 17, 2013
Page 30 of 90
tL0
The Daily Delivery Charge shall be equal to the 100% load factor equivalent of the FTS-I
E-2 rute, 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 %)] * 100% Load
Factor Equivalent FTS-l E-2
/8 Reserved
19 Reserved
The Reservation Rate shall be $0.02lDth applied to the MDQ of the 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.
Reserved/tt
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
ll3 Reserved
ll4 Reserved
l15 Reserved
116 Reserved
l17 Reserved
ll8 Reserved
lssued: July 25,2013
Effective: October l, 2013
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
Docket No. RPl 3-l 1 00-000
Accepted: September 17, 2013
Page 31 of90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
SHIPPER
Issued: June 9, 201 I
Effective: April I l,20ll
PART 4.8
4.8 - Statement of Rates
Negotiated Rate Agreements - ITS-1, PS-l and AIS-I
v.4.0.0 Superseding v.3.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FORTRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS-I, PS-I, AND AIS-I
TERM OF RATE
CONTRACT SCHEDULE DTH/D
PRIMARY
DELIVERY RATEPOINT 1213
Docket No. RP1 1-2 1 83-000
Accepted: July 8, 2011
Page 32 of 90
PRIMARY
RECEIPT
POINT
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: June 9, 201 I
Effective: April I l,20ll
PART 4.9
4.9 - Statement of Rates
Footnotes for Negotiated Rates - ITS-1, PS-l and AIS-l
v.4.0.0 Superseding v.3.0.0
Docket No. RPI I-2I83-000
Accepted: July 8, 2011
Page 33 of 90
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS-I, PS-I, AND AIS-1
Explanatory Footnotes for Negotiated Rates under Rate Schedule ITS-1, PS-I, and AIS-I
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.
13 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
Chevron 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., Inc.
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)
lssued: 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.CONFORMTNG SERVICE AGREEMENTS
PURSUANT TO $ 1s4.112(b)
Contract Rate Effective Termination
Name of Shipper Number Schedule Date Date
152
153
154
r58
163
167
168
169
170
177
178
179
180
181
r82
2591
2857
28s8
7828
803s
ll1
tt2
119
144
146
4621
4721
4770
6759
7047
7068
7804
7806
7807
7812
7816
8038
8176
8228
8318
FTS.1
FTS-1
FTS-1
FTS-1
FTS-1
FTS-1
FTS-1
FTS-1
FTS-I
FTS-1
FTS-1
FTS-1
FTS-1
FTS-1
FTS.I
FTS-1
FTS.1
FTS-1
FTS-1
FTS-I
ITS-1
ITS-1
ITS-I
ITS.l
ITS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-1
AIS-I
AIS-I
AIS-I
AIS-I
AIS-1
AIS-I
AIS.I
AIS-1
AIS-I
tt/1n993
tUUt993
t1/Ut993
tUUt993
tt/t/1993
tUUt993
tyUt993
tvyt993
tyUt993
tUyt993
tUUt993
t,/Ut993
tUUt993
tvUt993
t1/1/1993
8lUt995
ruyt995
tU1lt995
61312001
ry1l200t
2lUt992
4lyt992
4/22/1992
7 /23/1993
8lUt993
tznn996yUt997
U2511997
611711999
4n0t2000
4t27t2000
5130/2001
513012001
513012001
513012001
sl30l200r
81212001
1U27/2001
1/812002
411U2002
10t3y2023
10t312023
1013y2023
1013112013
1013U2023
10t3112023
10t3y2023
1013U2023
10t3y2023
t0t3t/2023
1013U2023
10t3112023
1013112023
10t31t2023
1013v2023
101312025
101312025
1013U2025
1013112025
t0t3y202s
t013t/2010
3l3t/2011
4l22l20tt
9t3012010
8t1/2010
12t312010
t2l3U20t0
t2/3U20r0
t2/31/2010
t2l3U20t0
t2t4t20t9
12131/2021
t2/3U2021
t2/3U2021
t2/3U2021
t2t3U202t
8t312021
1t/3012021
U31/2022
4t3012023
Docket No. RPl3-103-000
Accepted: October 23,2012
Page 34 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-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 l5
9149
9281
9285
9630
9774
10197
10308
10336
10359
10625
10639
10646
4576
4619
4720
4868
4908
5348
5677
5679
5837
s992
6226
6378
6613
706r
7798
7803
7805
7819
7820
7833
8037
8229
8283
83 r6
AIS-1
AIS-I
AIS-1
AIS-I
AIS-I
AIS-I
AIS-1
AIS-1
AIS-1
AIS-1
AIS-I
AIS-I
AIS.l
AIS-1
AIS-1
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS.I
AIS-I
AIS-I
PS.I
PS-1
PS-1
PS-I
PS-1
PS.1
PS-1
PS-I
PS-1
PS-I
PS-1
PS-I
PS-1
PS-I
PS-1
PS-I
PS-I
PS.I
PS-I
PS-1
PS-1
PS-I
PS-I
PS-1
7/3y2012
tzl3y20t2
3131/2013
6n312023
6/3012013
1r/3012013
7nt2011
2t2812014
3t3t2014
413012014
6/30t2014
713u2014
1013u2014
t0l3U20t0
5/3U2015
9130/2015
7l25l20tr
t013U201t
t013U20t0
t2/3U2010
4/30t2018
413012018
s/31/2018
12t3112010
t2l3U20t0
1213U2010
1213U2010
1213112010
1213U2010
1213U2010
1213U2010
5n7t2010
t2/3U2023
1213u2010
tzl3U20t0
t213U2010
412012020
1213U2021
1213112021
1213112021
1213112021
1213112021
618t2020
8/3U2021
t/312022
313U2022
413012023
7t22/2002yt/2003
311912003
611312003
7lt/2003
121U2003
121u2003
31U2004
31312004
4127/2004
711712004
811612004
1U812004
rl/t512004
61U2005
101v2005
712612006
1012712006
11/1/2006
12122/2006
411012008
4129/2008
s/30/2008
12nn996
tzlUt996
UUt997
3lyt997
3tsn997
71311997
t0l6lt997
t0l7lt997
t113lt997
2/13/1998
5lt4lt998
8l2slt998
t2lt4lt998
4120t2000
sl301200t
sl30l200t
sl30l200t
s13012001
sl30/2001
6lt4l200t
8/2t2001
U812002
311412002
411U2002
Docket No. RPI 3-103-000
Accepted: October 23, 2012
Page 35 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-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 Enerry 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 Enerry 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
8s34
8539
859s
8652
8668
8784
8873
8886
8923
9018
9173
9263
9273
9584
9772
9948
r0195
103 l0
10332
12071
PS-1
PS-1
PS-1
PS-I
PS-I
PS-1
PS-I
PS.I
PS-1
PS.1
PS-1
PS-1
PS.I
PS.1
PS-I
PS-I
PS-1
PS-1
PS-I
PS-I
PS.I
PS-I
FTS.l
411612002
51212002
712212002
tyt512002
121y2002
3n912003
s12312003
7n/2003
9lt0/2003
121U2003
121U2003
21U2004
41712004
8130/2004
10129/2004
tl4/2004
51212005
10lt/200s
2nt2006
7t26t2006
10127/2006
t1/y2006
tUU20t2
413012022
s13U2022
713u2012
10/3U20r2
ry30l20t2
313U2013
5t3u2013
613012013
813y2013
tU30t20t3
7nl20tt
13!2014
4t712014
8t30t2010
1013U2010
t0l3U20t4
413012015
913012015
u3112016
7lzsl20tt
10l3U20tt
t0l3u201l
313,/2018
Docket No. RPl 3- I 03-000
Accepted: October 23, 2012
Page 36 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I l,20ll
Effective: April4,2011
PART 5
RATE SCHEDULES
v.2.0.0 Superseding v.1.0.0
RATE SCI{EDULES
Firm Transportation Service (FTS-I)
Limited Firm Transportation Service (LFS-1)
Intemrptible Transportation Service (ITS- I )
Unbundled Sales Service (USS-I)
Parking Service (PS-l)
Authorized Imbalance Service (AIS- I )
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 37 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April ll,20ll
Effective: April 4, 201I
PART 5.1
5.1 - Rate Schedules
Rate Schedule FTS-I - Firm Transportation Service
v.2.0.0 Superseding v. 1.0.0
RATE SCHEDULE FTS.I
FIRM TRANSPORTATION SERVICE
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 38 of90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April 1l,20ll
Effective: April4, 201I
PART 5.I.I
5.1.1 - Rate Sched FTS-I
Availability
v.2.0.0 Superseding v. 1.0.0
5.I.1 AVAILABILITY
This rate schedule is available to any party (hereinafter called "Shipper") qualifying 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. 1-A.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 39 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April I l,20ll
Effective: April4, 201I
5.1.2 APPLICABILITY AND CHARACTER OF SERVICE
This rate schedule shall apply to frm 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- 1
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 40 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
lssued: May 26,2011
Effective: June27,20ll
PART 5.I.3
5.1.3 - Rate Sched FTS-I
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, Ovemrn 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 Tariffl Fourth
Revised Volume No. l-A are applied to transportation service rendered under this rate
schedule.
Docket No. RPI l-2132-000
Accepted: June l0,20ll
Page41 ofg0
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: May 26,2011
Effective: June27,20ll
PART 5.1.3.1
5.1.3.1- Rate Sched FTS-I
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-Mileage Component.
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. RPl l-2132-000
Accepted: June 10,201 I
Page 42 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April ll,20ll
Effective: April4, 2011
PART 5.1,3.2
5.1.3.2- Rate Sched FTS-l
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 Ovemrn) at point(s) of delivery on Mainline Facilities, and the
distance, in pipeline miles, from the point(s) of receipt to point(s) of delivery on
Mainline Facilities.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 43 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April ll,20ll
Effective: April4, 201I
PART 5.1.3.3
5.1.3.3- Rate Sched FTS-I
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 ofthe 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 l-1986-000
Accepted: May 4,2011
Page 44 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April ll,20ll
Effective: April4, 201I
PART 5.1,3.4
5.1.3.4- Rate Sched FTS-1
Authorized Ovemrn Charge
v.2.0.0 Superseding v.1.0.0
5.1.3.4 Authorized Overrun 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
Overruns shall not affect any Shipper's rights on the GTN System. Authorized
Overruns are interruptible in nature. The rate charged shall be the same as the
rates and charges for intemrptible transportation under Rate Schedule ITS-I as
set forth in Section 4.1, and such Authorized Overruns shall be subject to the
priority of service provisions of Section 6.19 of the Transportation General
Terms and Conditions.
Docket No. RP1 l-1986-000
Accepted: May 4,2011
Page 45 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April 11,2011
Effective: April4,20ll
PART 5.1.3.5
5.1.3.5- Rate Sched FTS-1
Appl icability o f 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 Tarifi Fourth
Revised Volume No. l-A. Such surcharges shall be deemed to be part of
Shipper's Reservation and Delivery Charges.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 46 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: August 1,2014
Effective: September l, 2014
PART 5.1.3.6
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. RPl4-1 I 54-000
Accepted: August 27, 2014
Page 47 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April 11,2011
Effective: April4, 201I
PART 5.1.3.7
5.1.3.7- Rate Sched FTS-I
Backhauls
v.2.0.0 Superseding v. 1.0.0
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.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 48 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 5.1.3.8
5.1.3.8- Rate Sched FTS-I
Capacity Release
v.2.0.0 Superseding v. 1.0.0
5.1.3.8 Capacity Release.
(a) Releasing Shippers:
Issued: April 1l,20ll
Effective: April4, 2011
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) Replacement Shippers:
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. 1-A. Charges to be
paid shall be the sum of the Reservation Charge, Delivery Charge, and
other applicable surcharges or penalties.
The rates paid by Shipper receiving capacity release transportation service
shall be adjusted as provided on Exhibit R in the executed Transportation
Service Agreement For Capacity Release between GTN and Shipper.
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 49 of 90
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 50 of 90
5.1.3.9 Reservation Chargq Credit - Force Majeure Event.
As used inthis Section 5.1.3.9, FirmDaily Volume shall meanthe 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. Ii 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. l-A
Issued: December 6, 2012
Effective: January 12, 2012
PART 5.1.3.r0
5. 1.3. 10-Rate Sched FTS-l
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
Page51 of90
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 confrmable 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. 1-A
Issued: December 6, 2012
Effective: January 12, 2012
PART 5.1.3.11
5.1.3. 1 l -Rate Sched FTS-1
Reservation Charge Credit - Confirmable Nominations
v.3.0.0 Superseding v.2.0.0
Docket No. RP12-15-005
Accepted: January 16, 2013
Page 52 of 90
5.1.3.11 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-1
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. RP14-l I 54-000
Accepted: August 27, 2014
Page 53 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I1,2071
Effective: April 4, 2011
PART 5.I.4
5.1.4 - Rate Sched FTS-I
Fuel and Line Loss
v.2.0.0 Superseding v. 1.0.0
5.I.4 FUEL AND LINE 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 1-1986-000
Accepted: May 4,2011
Page 54 of 90
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: April 1l,20ll
Effective: April4, 201I
5.I.5 TRANSPORTATION 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-I
Transportation General Terms and Conditions
v.2.0.0 Superseding v. 1.0.0
Docket No. RPI I - I 986-000
Accepted: May 4,2011
Page 55 of 90
Page I
Foothills Pipe Lines Ltd. Rate Schedule FT
RATE SCHEDULE FT
FIRM TRANSPORTATION SERVICE
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
(b) 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. SERVICE 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;
TARIFF _ PHASE I
Page 56 of 90
Effective Date: April 1,2007
Foothills Pipe Lines Ltd.
Page2
Rate Schedule FT
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,
Firm 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\[D 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 COMPAI\IIES AIID 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)
(c)
6.
6.1
TARIFF_PHASE I Effective Date: April 1,2007
Page 57 of 90
Page 3
Foothills Pipe Lines Ltd. Rate Schedule FT
Agreement, Firm Transportation Service with Company, shall conffact 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.
6.2
Subsidiary Company Zone No.
Foothills Pipe Lines 6
(Alta.) Ltd.
Foothills Pipe Lines
(South B.C.) Ltd.
Foothills Pipe Lines
(Sask.) Ltd.
Description
From Caroline, Alberta to the
Alberta/ Saskatchewan border
near Empress, Alberta.
From Caroline, Alberta to the
Alberta/B.C. border near
Coleman, Alberta.
Length
(km)
378.49
124.03
From the Alberta/B.C. border 170.7
near Coleman, Alberta to the
8.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 Service
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 1,2007
Page 58 of 90
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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 of gas which has an aggregate energy content of all 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 7.2.2hercin, 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.
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 59 of 90
7.3
TARIFF_PHASE I
8.
8.1
Foothills Pipe Lines Ltd.
Page 5
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 SERYICE
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 8.2.2hereof. 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 60 of 90
8.2
TARJFF - PHASE I
Foothills Pipe Lines Ltd.
Page 6
Rate Schedule FT
(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 and Zone 9 to service to Shipper under Rate Schedule IT,
Intemrptible Service and for Zone 6 and Zone 7 to Shipper under Rate Schedule
OT, Ovemrn Transportation Service.
Effective Date: April 1,2007
Page 6'l of 90
TARIFF -PHASE I
Foothills Pipe Lines Ltd.
PageT
Rate Schedule FT
8.4 Charge for Over-Run Gas inZone 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 DELIVER GAS
General
If 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 1,2007
Page 62 of 90
8.5
9.
9.1
9.2
TARIFF _PHASE I
Foothills Pine Lines Ltd.
Page 8
Rate Schedule FT
9.3
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 1.2 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 63 of 90
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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 AI\D 9
10.1 Availability
Shippers to whom renewal rights are available, shall have the option ("Renewal Option")
of extending the existing tenn 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:
10.
(a)
(b)
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;
TARIFF _PHASE I Effective Date: April l, 2007
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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 65 of 90
TARIFF-PHASE I
Foothills Pipe Lines Ltd.
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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.
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.
RENEWAL RIGHTS IN ZONE 8
10.3
11.
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 (l) year prior to termination of Shipper's
Service Agreement, Firm Transportation Service. If Shipper does not provide such
Effective Date: April 1,2007
Page 66 of 90
TARIFF_PHASE I
NOVA Gas Transmission Ltd.
Page 1
FT.R
Rate Schedule
1.0
1.1
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.
Eflective Date: January 1,2014 Page 67 of 90
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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 95%o (Price Point "A");
(ii) at least three (3) years but less than five (5) years the Price Point shall be 100%
(Price Point "B"); and
(iii) 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 SERVICE
4.1 Aggregate of Customer's 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 (FrPl(t r+)'( c )
Effective Date: January 1,2014 Hage ou oT 9u
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Page 3
FT.R
Rate Schedule
66F"
Where:
66MDC"
(6P"
(6A"
6'8"
(.c))
the aggregate of the demand charges applicable to such Schedule
of Service for such Billing Month;
the FT-R Demand Rate applicable to such Schedule of Service;
the applicable Price Point for such Schedule of Service;
each Receipt Contract Demand in effect for all or a portion of such
Billing Month for such Schedule of Service;
the number of days in such Billing Month that Customer was
entitled to such Receipt Contract Demand under such Schedule of
Service; and
the number of days in such Billing Month.
4.2
4.3
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 fonh in the Table of Rates, Tolls and Charges applicable to each of
Customer's Schedules of Service under Rate Schedule FT-R.
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 V
Effective Date: January 1,2014
xZ
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Ptge 4
FT-R
Rate Schedule
Where:
..MOC"
"v"
'(2"
the monthly charge for Over-Run Gas at such Receipt Point;
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
the IT-R Rate at such Receipt Point.
4.4
4.5
The calculation of Customer's charge for Over-Run Gas in paragraph 4.3 shall not take
into account Customer's Inventory on the last day of the Billing Month.
Aggregate Charge For Service
Customer shall pay for each Billing Month:
the sum of the amounts calculated in accordance with paragraphs 4.1,4.2, and
4.3; less
the amount, if any, calculated in accordance with the Terms and Conditions
Respecting Relief for Mainline Capacity Restrictions in Appendix "8" of the
Tariff.
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:
(D
(ii)
4.6
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FT.R
Rate Schedule
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.
If 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
paragraph4.3.
TERM OF SERVICE
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
(D
(ii)
(iii)
(iv)
5.0
5.1
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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
s.3
5.4
The Price Point for the term shall be determined in the manner described in paragraph
3.2.
lf 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.
CAPACITY RELEASE
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
6.0
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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
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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
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 8.1, but
may permit such transfer provided that:
8.2
(D
(i i)
(iiD
(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 affributable to the transfer is not required;
the transfer does not occur during the Primary Term of the Schedule of Service;
the Price Point in effect for Service under the Schedule of Service, from which
Customer wishes to transfer Service at the time of the transfer, 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 transfer of Service agreement.
(v)
(vi)
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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
specifring 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:
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;
(iv) 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;
(v)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 transfened 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
8.4
(i)
(ii)
(i ii)
(vi)
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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 specifuing 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)
(ii)
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FT.R
Rate Schedule
(iv)
(v)
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.(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 speciSing 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
Eflective Date: January 1,2014 Page 77 of 90
NOVA Gas Transmission Ltd.
Page12
FT.R
Rate Schedule
(iD 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;
(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 l,2014 Fage /6 or vu
NOVA Gas Transmission Ltd.
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.
1O.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 lnventory 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 (l)
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.
Eflective Date: January 1,2014 Page //9 ot 90
NOVA Gas Transmission Ltd.
Page 14
FT.R
Rate Schedule
ll.2 lrrevocableNotice
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 AIID CONDITIONS
13.1 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 6u oI 90
NOVA Gas Transmission Ltd.
Page 15
FT-R
Service Agreement
SERVICE AGREEMENT
RATE SCHEDULE F'T.R
BETWEEN:
NOVA Gas Transmission Ltd., a body corporate having an office in
Calgary, Alberta ("Company")
-and-
o, a body corporate having an office in o, . ("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 Tariff.
The capitalized terms used in this Service Agreement have the meanings affributed 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.
1.
2.
3.
4.
Eflective Date: January 1,2014 Page 81 of90
NOVA Gas Transmission Ltd.
Page 16
FT.R
Service Agreement
5.Customer shall:
(a)
(b)
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 arangements 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.
6.
Effective Date: January 1,2014 Page EZ ot 90
NOVA Gas Transmission Ltd.
Page 17
FT-R
Service Agreement
7. 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:
Attention:
Fax: .
comnalr:
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.
a
o
a
a
Effective Date: January 1,2014 rage uJ or vu
NOVA Gas Transmission Ltd.
Page 18
FT.R
Service Agreement
(a) Notwithstandingtheforegoing:
(D Company may give any Notice on the Website; and
(ii) 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 (1) 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 authorized in that behalf all as of the o d4y sf o, o.
Per:
NOVA Gas Transmission Ltd.
Per:
Per:
Effective Date: January 1,2014
Per :
Page u4 or 90
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Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
TRANSPORTATION SERVICE . SOUTHERN
DEF!NITIONS
1. ln this Toll Schedule, the following term shall have the following meaning:
(a).'@'meanSTransportationService-Southernprovided
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),.@,'meanSthepointontheinternationalboundarybetween
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)..@''meansinrespectofeachFirmTransportationService.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 - Southem, 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 8.1
Effective Date: April 1,2014
Page 86 of 90
Page 8.2
Effective Date: April 1,2014
Page 87 of 90
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
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 TMNSPORTATION 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 Commodi$ 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 otherwise 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
6.
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
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.
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 equal to 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 8.3
Effective Date: April 1,2014
Page 88 of 90
Page 8,4
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
APPENDIX A
DEMAND AND COMMODITY TOLLS
TRANSPORTATION SERVICE . SOUTHERN
Firm Transportation Seruice - Southern
Demand Tolls
$/103m3/mo.
PNG lnland Huntingdon
FortisBC
Kingsvale to
Service Term Delivery Point Delivery Area Delivery Area* Huntingdon'*
1 year
2 years
3 years
4 years
5 years or more
Months
102.95 268.02
99.95
96.95
95.95
94.95
454.41
260.22 441.17
252.41 427.94
249.81 423.53
247.21 419.11
186.38
180.96
175.53
173.72
171.91
* 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 - Southem 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 Service
Commoditv Tolls
$/103;3
PNG lnland Huntingdon
FortisBC
Kingsvale to
Delivery Point Delivery Area Delivery Area Huntingdon"
November to March
April to October
4.089
3.271
10.645
8.516
18.048
14.438
7.403
5.922
* 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.
Effective Date: April 1,2014
Page 89 of 90
Page 8.5
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
lnterruptible Transportation Seruice - Southern
Commoditv Tolls
$/103;3
FortisBCPNG lnland Huntingdon Kingsvale toMonths Delivery Point Delivery Area Delivery Area Huntingdon
November to March 4.885
Aprilto October 3.706
12.719 21.564
9.649 16.359
8.845
6.710
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.
lmport Backhaul Service
Commoditu Tolls
s/103;3
lnland PNG CompressorMonths Deljygrv Area_ Delivery Point Station No. 2
Novemberto March 8.845 16.679 21.564
April to October 6.710 12.653 16.359
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.
Effective Date: April 1, 2014
Page 90 of 90