20190823Application.pdf

Avista Corp.
141 1 East Mission P.O. Box 3727
Spokane, Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
August 22,2019
Diane Hanian
State of ldaho
Idaho Public Utilities Commission
472 W. Washington Street
Boise, Idaho 83702-5983
Case No. AVU-G-1g-O1r/Advice No. l9-02-G
I.P.U.C. No.27 - Natural Gas Service
Enclosed for filing with the Commission are the Original filing plus seven copies, and one compact disc,
of the following revised tariff sheets:
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Twenty-Seventh Revision Sheet 150 canceling
Twenty-First Revision Sheet 155 canceling
Twenty-Sixth Revision Sheet 150
Twentieth Revision Sheet 155
The Company requests that the proposed tariff sheets be made effective November 1,2019. These tariff
sheets reflect the Company's annual Purchased Gas Cost Adjustment ("PGA"). If approved, the
Company's annual revenue will increase by approximately $3.3 million or approximately 5.6yo. The
proposed changes have no effect on the Company's earnings. 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 commercialcustomer using an average of 64
therms per month will see an increase of $2.26 per month, or approximately 4.8oh. The present bill for 64
therms is $47.62 while the proposed bill is $49.88. The Company will issue a notice to its customers
through a bill insert in the September 2019 to October 2019 timeframe. A copy of the bill insert has been
included in the Company's filing.
If you have any questions regarding this filing, please contact Kaylene Schultz at [phone] or
Annette Brandon at [phone].
Patrick D. Ehrbar
Director of Regulatory Affairs
a
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that I have served Avista Corporation dba Avista Utilities'Advice filing
ADV 19-02-G (Tariff IPUC No.27 Natural Gas Service) by mailing a copythereof, postage
prepaid to the following:
Diane Hanian, Secretary
ldaho Public Utilities Commission
472W . Washington Street
Boise, lD 83720-5983
Edward A. Finklea
Alliance of Western Energy Consumers
545 Grandview Drive
Ashland, OR 97520
Chad Stokes
Cable Huston Benedict Haagensen &
Lloyd, LLP
1455 SW Broadway, Suite 1500
Portland, OR 97201
Curt Hibbard
St. Joseph Regional Medical Center
PO Box 816
Lewiston, lD 83501
Dated at Spokane, Washington this 22th day of August 2019
Paul Kimball
Manager Regulatory Compliance & Discovery
REC E IVED
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
:II9 f,UC 28 PH 2: h5
,.,,',:ii=.irhti'5 [8*, *n
IN THE MATTER OF THE APPLICATION OF )
AVISTA UTILITIES FOR AN ORDER APPROVING ) CASE: AVU-G-19-0Q
A CHANGE IN NATURAL GAS RATES AND CHARGES )
Application is hereby made to the Idaho Public Utilities Commission for an Order approving a revised
schedule of rates and charges for natural gas service in the state of Idaho. The Applicant requests that
the proposed rates included in this Purchased Gas Cost Adjustment ("PGA") filing be made effective on
November 1,2019. If approved as filed, the Company's annual revenue will increase by approximately
$3.3 million or about 5.6%. In support of this Application, Applicant states as follows:
The name of the Applicant is AVISTA CORPORATION, doing business as AVISTA UTILITIES
(hereinafter Avista, Applicant or Company), a Washington corporation, whose principal business office
is l4l1 East Mission Avenue, Spokane, Washington, and is qualified to do business in the state of Idaho.
Applicant maintains district offices in Moscow, Lewiston, Coeur d'Alene, Sandpoint, and Kellogg,
Idaho. Communications in reference to this Application should be addressed to:
Patrick D. Ehrbar
Director of Regulatory Affairs
Avista Utilities
1411 E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
Pat. ehrbar@avistacorp. com
il.
Attorney for the Applicant and his address is as follows:
David J. Meyer
Vice President and Chief Counsel for Regulatory
And Govemmental Affairs
Avista Utilities
l4l I E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
David.meyer@avistacorp. com
I
Case No. AVU-G-19-0_ (Advice No. l9-02-G)Page I of6
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
Twenty-Seventh Revision Sheet 150, which Applicant requests the Commission approve, is filed
herewith as Exhibit "A". Additionally, Twenty-First Revision Sheet 155, which Applicant requests the
Commission approve, is also filed herewith as Exhibit "A". Also included in Exhibit "A" is a copy of
Twenty-Seventh Revision Sheet 150 and Twenty-First Revision Tariff Sheet 155 with the changes
underlined and a copy of Twenty-Sixth Revision Sheet 150 and Twentieth 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.
VI
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 ldaho, a Notice in the form attached
hereto as Exhibit "B" and by means of a press release distributed to various informational agencies, a
draft copy attached hereto in Exhibit "F". In addition, Exhibit "F" to this Application also contains the
form of customer notice that the Company will send to its customers in its monthly bills in the September
- October timeframe.
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), TC Energy - Alberta, TC Energy - BC and Enbridge 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 2019 through October 2020 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 rate changes reflected in this filing:
Case No. AVU-G-19-0_ (Advice No. l9-02-G)Page 2 of 6
(Revenue Sensitized)
Service
General
Lg. General
Lg General
Interruptible
Transportation
Commodity Demand
Change Change
per therm per therm
$ (0.01697) $ (o.oo2eo)
$ (0.016e7) s (0.002e0)
$ (0.016e7) $ (0.002e0)
$ (0.0r697) $
$-$
Amortization TotalRate Overall
Change Change Percent
per therm per therm Change
$ 0.05520 $ 0.03533 5.2"/"
$ 0.0ss20 $ 0.03s33 4.9v"
$ $ (0.01987) -2.6oh
s $ (0.016e7) -4.6Vo
$ 0.00265 $ 0.00265 2.1"
Sch.
No.
l0l
lll
112
131
146
Total
Sch.150
Change
$ (0.0re87)
$ (0.01e87)
s (0.0re87)
$ (0.016e7)
$-
x
Commoditv Costs
As shown in the table above, the estimated WACOG change is a decrease of $0.01 697 per therm. The
proposed WACOG $0.15328 per therm compared to the present WACOG of $0.17025 per therm
included in rates. The overall reduction in the WACOG is generally the result of the continued high
natural gas production levels and an abundance ofnatural gas in storage.
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 the previous
thirty-six months for the forthcoming PGA year. Approximately 43%o of estimated annual load
requirements for the PGA year Qrlovember 2019 through October 2020) will be hedged at a fixed-price
derived from the Company's Plan. Through July, the hedge volumes for the PGA year have been
executed at a weighted average price of $1.71 per dekatherm ($0.171 per therm).
The Company used a 30-day historical average of forward prices and supply basins (ending July 31,
2019) 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 57o/o of estimated annual load requirements
for the coming year. The annual weighted average price for these volumes is $1.58 per dekatherm
($0.158 per therm).
Case No. AVU-G-19-0_ (Advice No. l9-02-G)Page 3 of6
X.
Demand Costs
Demand costs reflect the cost of pipeline transportation to the Company's system, as well as fixed costs
associated with natural gas storage. As shown in the table above, demand costs are expected to slightly
decrease for residential customers by approximately $0.00290 per therm. This reduction is related to a
reduction of various factors including Canadian exchange rate, updated demand forecast, and changes
due to federal tax reform for Gas Transmission Northwest (GTN), etc.
XI.
Schedule 155 / Amortization Rate Chanee
As shown in the table above, the proposed amortization rate change for Schedule 101 and Schedule 111
is an increase in revenue (or reduction in current rebate) of $0.05520 per therm. The current rate
applicable to Schedule 101 and Schedule 111 is $0.09145 per therm in the rebate direction;the proposed
rate is $0.03625 per therm also in the rebate direction.
For the previous PGA year, the Company was able to secure commodity expense at much lower than
what was embedded in customer rates, which resulted in a total rebate balance of $7.9 million or
$0.09145 per therm.r
For the 2018-2019 PGA year, conditions were not as favorable, which resulted in a smaller deferral
balance of approximately $1.2 million. A combination of various factors contributed to higher actual
wholesale natural gas prices versus the previous year. Regionally, actual wholesale natural gas prices
exhibited extreme volatility and higher prices after the Enbridge-owned West Coast Pipeline
("Enbridge") experienced a rupture in October 2018. The pipeline has since been repaired, but has been
operating at reduced capacity especially throughout the 2018-2019 winter. The capacity shortage on
Enbridge severely affected the natural gas supply in the Pacific Northwest during the winter months,
driving prices and volatility higher. This relatively mild winter regionally turned very cold in February
2019. The arrival of cold weather, coupled with the loss of one of the compressors at the Jackson Prairie
storage facility for a three-week period, further exacerbated the capacity shortage, increasing regional
spot natural gas prices, including record high prices at the Sumas natural gas trading hub.
In this year's filing, the Company has included a projection of defenal and amortization balances from
July 2019 through October 2019. The volatility experienced in the previous winter was unusual and has
not, nor is expected to, continue throughout the rest of the PGA year. Therefore, in order to provide
customers the benefit from these lower prices in a timely manner, we have included an estimate of
commodity and demand deferrals of approximately $3.2 million which we believe will occur from July
2019 through October 2019, prior to the next natural gas PGA year. This estimate is based on an average
of the previous three years of commodity and demand deferrals. In total, the combination ofthe Deferral
balance as of June 30,2019 plus the projected amortization and deferrals for July 2019 through October
2019 results in a net deferral balance of $3.2 million, or $0.03625 per therm.
I In addition to the S7.9 million related to Commodity and Demand Deferrals, was $65,27 l.6l related to a residual Idaho
Earnings Test Deferral and $579,410.11 related to residual Temporary Tax Benefits.
Case No. AVU-G- l9-0_ (Advice No. l9-02-G) Page 4 of 6
XII
If approved as filed, the Company's annual revenue willincrease by approximately $3.3 million or about
5.6Yo effective November I , 2019. Residential or small commercial customers using an average of 64
therms per month would see an increase of $2.26 per month, or approximately 4.8o/o. The present bill
for 64 therms is $47.62 while the proposed bill is $49.88.
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,
2019, 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 1,2019.
Dated at Spokane, Washington, this 22"dday of August 2019
AVISTA UTILITIES
BY
. Meyer
Vice President and Chief Counsel for
Regulatory & Governmental Affairs
Avista Corporation
Case No. AVU-G-19-0_ (Advice No. l9-02-G)Page 5 of6
VERIFICATION
STATE OF WASHINGTON
County of Spokane
David J. Meyer, being first duly sworn on oath, deposes and says: That he is the Vice President
and Chief Counsel for Regulatory & Governmental Affairs for Avista Utilties 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 22"d day of August 2019,by David J. Meyer
ARY PUBLIC in and for the State of
Washington, residing at Spokane.
Commission Expires:vltqtTw
)
)
)
KRISTA A BREWER
Notary Public
State of Washington
Commission il 154573
My Comm. Expires Dec 14,2O22
1fr6
Case No. AVU-G-19-0_ (Advice No. 19-02-G)Page 6 of6
DAVID J. MEYER
VICE PRESIDENT AND CHIEF COLINSEL FOR
REGULATORY & GOVERNMENTAL AFFAIRS
AVISTA CORPORATION
P.O. BOX 3727
1411 EAST MISSION AVENUE
SPOKANE, WASHINGTON 99220 -37 27
TELEPHONE: (s09) 495-4316
FACSIMILE: (509) 495-885 I
DAVID.MEYER@AVISTACORP. COM
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF AVISTA CORPORATION FOR AN
ORDER APPROVING A CHANGE
IN NATURAL GAS RATES AND CHARGES
TO NATURAL GAS CUSTOMERS IN THE
STATE OF IDAHO
)
)
)
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CASE NO. AVU-G-I9-ta
ATTORNEY' S CERTIFICATE
CLAIM OF CONFIDENTIALITY
RELATING TO PORTIONS
OF AVISTA'S EXHIBIT'S
AND WORKPAPERS
1
2
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4
5
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8
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FOR AVISTA CORPORATION
I, David J. Meyer, represent Avista Corporation. I am Vice President and Chief
Counsel for Regulatory and Governmental Affairs for Avista Corporation (Avista or
Company) and I am appearing on its behalf in this proceeding.
I make this certification and claim of confidentiality pursuant to IDAPA 31.01.01
because Avista, through its supporting workpapers, is disclosing certain information that
is CONFIDENTIAL and constitutes TRADE SECRETS as defined by Idaho Code
Section 9-340 and 48-801 and protected under IDAPA 31.01.01 .067 and 31.01.01.233.
The printed information Avista provides will, as required under IDAPA Rule
31.01.01 .067,be marked as CONFIDENTIAL, will be reproduced on any colored paper
other than white, and will be provided under separate cover. The electronic information
Avista provides will be reproduced separately on a compact disk (CD) and will also be
marked as CONFIDENTIAL.
The confidential information that Avista is disclosing includes, but is not limited
to certain forward wholesale natural gas pricing which is provided by a third-party
vendor, who does not allow public access to their proprietary information. Avista herein
asserts that the aforementioned information is confidential in that making third-party
pricing data public will violate the terms of our agreement with the vendor.
I am of the opinion that this information is CONFIDENTIAL, as defined by Idaho
Code Sections 9-340D and 48-801, should therefore be protected from public inspection,
examination and copying, and should be utilized only in accordance with the terms of the
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77
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ATTORNEY'S CERTIFICATE - I
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PROTECTIVE AGREEMENT BETWEEN AVISTA CORPORATION AND PARTIES
WHO HAVE REQUESTED SUCH AN AGREEMENT.
RESPECTFULLY SUBMITTED this 22nd day of August 2019
. Meyer
President and Chief Counsel for
Regulatory & Governmental Affairs
Avista Corporation
ATTORNEY'S CERTIFICATE - 2
AVISTA UTILITIES
Case No. AVU-G-19-0la_
EXHIBIT "A"
Proposed Tariff Sheets
l.P.U.C. No.27
lssued by
By
Avista Utilities
Twenty-Seventh Revision Sheet 150
Replacing
Revision Sheet 150
Patrick Ehrbar - Director of Regulatory Affairs
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
natural gas, to become effective as noted below.
RATE:(a) The retail rates of firm gas Schedules 101 , 1 1 1 and 112 are to be increased
by 24.678i, per therm in all blocks of these rate schedules.
(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 9.3500 15.3280, 24.6780,
Schedules 111 and 112 9.3506 15.3280, 24.678i,
Schedules 131 and 132 0.000/ 15.3280, 15.3280,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 9.295Q, 15.2390 24.5340,
Schedules 111 and 112 9.295Q, 15.2390, 24.534Q,
Schedules 131 and 132 0.0000 15.239i, 15.2390,
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company will maintain a Purchase Gas Adjustment (PGA) Balancing Account
whereby monthly entries into this Balancing Account will be made to reflect differences
between the actual purchased gas costs collected from customers and the actual
purchased gas costs incurred by the Company. Those differences are then collected from
or refunded to customers under Schedule 155 - Gas Rate Adjustment.
lssued August 23,2019 Effective November 1, 2019
a VgLbL
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
15.3280, per therm.
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 26S65d per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased
by a745i, per therm.
(c)The rate for transportation under Schedule 146 is to be decreased by
0.000d per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 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 0.0000 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.
lssued August 24,2018 Effective November1,2018
Twenty-Sixth Revision Sheet 150
l.P.U.C. No.27
Replacing
Revision Sheet 150 150
lssued by
By
Avista Ut
Patrick Ehrbar - Director of Regulatory Affairs
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 24.678i, per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased
by 15.328$ per therm.
(c)The rate for transportation under Schedule 146 is to be decreased by
0.0006 per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 101 9350A 15.328d, 24.678d,
Schedules 111 and 112 9.350d, 15.3284 24.678d,
Schedules 131 and 132 0.0000 15.328A 15328A,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 9.2954 15.2394 24.$44
Schedules 111 and 112 9.2954, 15.2396, 24.$44,
Schedules 131 and 132 0.000d 15.239G, 15.239d,
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company will maintain a Purchase Gas Adjustment (PGA) Balancing Account
whereby monthly entries into this Balancing Account will be made to reflect differences
between the actual purchased gas costs collected from customers and the actual
purchased gas costs incurred by the Company. Those differences are then collected from
or refunded to customers under Schedule 155 - Gas Rate Adjustment.
lssued August 23,2019 Effective November1,2019
Twenty-Seventh Revision Sheet 150
Replacing
Twenty-Sixth Revision Sheet 150 150l.P.U.C. No.27
lssued by
By
Avista
Patrick Ehrbar - Director of Regulatory Affairs
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 3.625$ per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0.0000 per therm.(c) The rate of transportation gas Schedule 146 is to be decreased by 0.0000
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
1 58.
lssued August 23,2019 Effective November 1,2019
l.P.U.C. No.27
Twenty-First Revision Sheet 155
Canceling
Twentieth Revision Sheet 155 155
lssued by
By
Avista Utilities
Patrick Ehrbar, Director of Regulatory Affairs
Vgk-L
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.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 9Ja5$ per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0.0000 per therm.(c) The rate of transportation gas Schedule 146 is to be decreased by ffiO
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
1 58.
lssued August 24,2018 Effective November1,2018
l.P.U.C. No.27
Twentieth Revision Sheet 155
Canceling
Nineteenth Revision Sheet 155 155
By Patrick Ehrbar, Director of Regulatory Affairs
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
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 3.625$ per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
0.0000 per therm.(c) The rate of transportation gas Schedule 146 is to be decreased by 0.000d
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
1 58.
lssued August 23,2019 Effective November1,2019
l.P.U.C. No.27
Twenty-F i rst Revis ion
::?::ffi ;
Twentieth Revision Sheet 155 155
By Patrick Ehrbar, Director of Regulatory Affairs
AVISTA UTILITIES
Case No. AVU-G- 19-01a_
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
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.
Twenty-First Revision Sheet 155 updates the amortization rate used to refund or recover previous gas cost
differences and Twenty-Seventh Revision Sheet 150 updates the forward-looking cost of natural gas purchased
for customer usage.
These tariffs request an annual revenue increase of approximately $3.3 million, or about 5.60%. This filing
requests an effective date of November 1,2019.
PGAs are filed each year to balance the actual cost of wholesale natural gas purchased by Avista to serve
customers with the amount included in rates. This includes the natural gas commodity cost as well as the cost to
transport natural gas on interstate pipelines to Avista's local distribution system. If the request is approved,
Avista residential customers using an average of 64 therms per month would see their monthly bill to increase
from$47.621o$49.88,beginningNov. l,2019,anincreaseof$2.26or4.8percent.Avista'snaturalgasrevenues
would increase by $3.3 million, or approximately 5.6 percent. The requested natural gas rate change by customer
segment is as follows:
Twenty-Seventh Revision Sheet 150 canceling
Twenty-First Revision Sheet 155 canceling
General Service - Firm - Schedule 101 - Residential & SmallCommercial
Large General Service - Firm - Schedules - Commercial lll & l12
High Annual Load Factor Large - Interruptible Service Schedules 132
Twenty-Sixth Revision Sheet 150
Twentieth Revision Sheet 155
4.8%
8.9%
2.0%
Avista does not mark up the cost of natural gas purchased to meet customer needs, so the filing does not increase
or decrease company earnings.
The Company's application is a proposal, subject to public review and a Commission decision. Copies of the
application are available for public review at the offices of both the Commission and Avista, and on the
Commission's website (www.puc.idaho.gov). Customers may file with the Commission written comments related
to the Company's filings. Customers may also subscribe to the Commission's RSS feed
(http://www.puc.idaho.gov/rssfeeds/rss.htm) to receive periodic updates via e-mail about the case. Copies of rate
filings are also available on our website, www.mlzavista.com/rates.
If you would like to submit comments on the proposed rate decrease, you can do so by going to the Commission
website or mailing comments to:
Idaho Public Utilities Commission
P. O. Box 83720
Boise, lD 83720-0074
Copies of the proposed tariff changes are also available for inspection in the Company's offices, its website
(www.mlzavista.com/rates), by calling [phone] or by writing:
Avista Utilities
Attention: Director of Regulatory Affairs
P.O.Box3727
Spokane, W A. 99220-3727
August 23,2019
AVISTA UTILITIES
Case No. AVU-G-19-06
EXHIBIT "D"
Lost and Unaccounted For Calculation
I
12 MOilTHS ENDED TOTAL
LOSS & UNAGCOUNTED FOR GAS
BY DELIVERY POINT. THERMS
WASHINGTON
WA SPO-CDA area
WA LEWIS-CLARK area
Colfax
Colton
Connell
Endicott
Goldendale
LaCrosse
Lind
Medical Lake
Palouse-Albion
Pullman
Ritzville-Spra g ue-Keystone
Rosalia
Saint John
Spangle
Stevenson
Union Town
Warden
WASHINGTON TOTAL
6,012,900 5,772,329 210,571 1.17
r,300,030
175,770
7,843,310
111,200
1,053,450
151,270
r63,990
6,473,160
496,000
17,942,930
1,021,280
225,560
261,750
316,730
73',t,220
122,510
DELIVERY
59,041,953
58,654,320
1,715,351
172,446
7,718,516
141,584
1,048,673
r36,194
159,662
5,196,641
442,337
't7,473,338
1,059,096
226,820
244,7',16
87,350
732,136
120,223
REVENUE
58,572,086
57,785,610
(445,3211
3,321
91,761
2,6r6
1,777
18,076
4,328
276,519
53,663
469,592
(37,816)
(1,260)
17,034
229,380
(s16)
2,287
(2s.sl )
1.93
1.22
1.85
0.46
13.27
2.71
4.46
12.13
2.69
(3.s7)
(0.56)
6.96
262.60
(0.1s)
1.90
IDAHO
lD SPO-CDA area
lD LEWIS-CLARK area
Bonners
Genesee
Kellogg
Moscow
Pinehurst-Kingston
Sandpoint
Smelterville-Page
IDAHO TOTAL
COLFAX
COLTON
ENDICOTT
GENESEE
LEWS.CLARK
MOSCOW
PALOUSE.ALBION
PULLMAN
UNION TOWN
LOSS +r-
469,867
868,710
olo OF
PURCHASE
0.80
1.50
117,696,273 116,357,696 1,338,577 1.15
3,129,820
282,120
4,736,430
7,467,890
894,'t00
8,670,780
498,550
5,681,978
256,712
4,953,{30
7,458,375
550,98,1
5,965,821
791
14'.1 6
1,745,351
't72,116
1r11,584
256,712
63,193,314
7,458,375
442,337
1 7,473,338
't20,223
(2,5s2,1 58)
25,378
(21 6,700)
9,515
343,116
2,704,959
(l44.921
9.88
(4.38)
0.13
62.27
45.34
53.50
Palouse lnterconnect Line (WA and lD):
1,300,030
175,770
111,200
282,120
64,143,320
7,467,890
496,000
17,942,930
122,510
1445,3211
3,324
2,616
25,378
950,006
9,515
53,563
469,592
2,287
(2s.51)
1.93
1.85
9.88
1.50
0.13
12.13
2.69
1.90
92,O74,770
2019 ldaho PGA Exhibit D - Lost and Unaccounted For GLOSS12
91,003,709 1,071,061
Page 1 of 1
1.18
olo OF
OELIVERY REVENUE LOSS+IGAIN PURCHASE
233,555,747 23't,697,067 1,858,680 0.80
5,489,000 5,407,704 81,296 1.50
239,011,717 237,101,771 1,939,976 0.82
AVISTA UTILITIES
Case No. AVU-G-19-09_
EXHIBIT (EE)'
Pipeline Tariffs
Exhibit E - Pipeline Tariff Sheets Page 1 of 42
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Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
DAILY
MILEAGE (a)
(Dth-MILE)
Max. Min'
BASE 0.000391 0.000000
STF (e) (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-r (0 0.002483 0.000000
E-2 (h) 0.002972 0.000000
(Diamond l)
E-2 (h) 0.001166 0.00oooo
(Diamond 2)
COYOTE SPRINGS
E-3 (i) o.o0l154 0.000000
CARTYLATERAL
E-4 (p)
ovERRr.rN CHARGE o
SURCHARGES
ACA (k)
Issued: November 30, 2018
Effective: January 7,2019
PART 4.I
4.1 - Statement of Rates
FTS-I, LFS-I, and FHS Rates
v. 1 8.0.0 Superseding v. I 7.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-I, LFS-I, and FHS
For Rate Schedules FTS-1 and LFS-I:
RESERVATION
DAILY
NON-MTLEAGE (b)
(Dth)
Max. Min.
0.030954 0.000000
(e) 0.000000
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
FIJEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%
0.00s0% 0.0000%
0.004177 0.000000 0.000026
0.000000
0.000026
0.000000
0.000000 0.000000
0.001 r 5s 0.000000 0,000000 0.000000
0.149828 0.000000 0,000000 0.000000
(k) (k)
Docket No. RPI 9-370-000
Accepted: January 2, 2019
Exhibit E - Pipeline Tariff Sheets Page 3 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.1
4.1 - Statement of Rates
FTS-I, LFS-I, and FHS Rates
v. 1 8.0.0 Superseding v. I 7.0.0
For Rate Schedule FHS:
The Mainline and Extension Reservation rates shown above for Rate Schedules FTS-I and
LFS-I shall also be applicable to service under Rate Schedule FHS, except that the Mileage and
Non-Mileage Components shall be adjusted to reflect the expedited hours of gas flow ("HF")
utilizing the following formulas, rounded to 6 decimal places:
(a) Mileage Reservation Component = FTS-IM x Miles x(24tHF)
(b) Non-Mileage Reservation Component = FTS-INM x (24lHF)
where:
Issued: November 30, 2018
Effective: January L, 2019
Applicable FTS-l Mileage Reservation Charge
Applicable FTS- I Non-Mileage Reservation Charge
Distance, in pipeline miles, from the Primary Point(s)
of Receipt to the Primary Point(s) of Delivery as set
forth in Shipper's Contract
MDQ/MHQ
Docket No. RPI 9-370-000
Accepted: January 2, 2019
FTS.IM :
FTS-INM :
Miles =
HF
Exhibit E - Pipeline Tariff Sheets Page 4 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
PART 4.2
4.2 - Statement of Rates
ITS-I and IHS Rates
v.9.0.0 Superseding v. 8.0.0
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)
(Dth)
Max. Min.
(e) 0.000000
DELIVERY (c)
(Dth-Mile)
Max. Min.
0.000016 0.000016
Fr.rEL (d)
(Dth-Mile)
Mu. Min.
0.0050% 0.0000o/o
EXTENSION CHARGES
MEDFORD
E-l (Medford) (0
0.002483 0,000000
COYOTE SPRINGS
E-3 (Coyote Springs) (i)
0.001154 0.000000
CARTYLATERAL
E-4 (Caxty Lateral) (p)
SURCHARGES
ACA (k)
0.004177
0.001155
0.1 49828
(k)
0.000000
0.000000
0.000000
(k)
0.000026
0.000000
0.000000
0.000026
0.000000
0.000000
Issued: November 30, 2018
Effective: January 1,2019
Docket No. RPl9-370-000
Accepted: January 2, 2019
Exhibit E - Pipeline Tariff Sheets Page 5 ol 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.2
4.2 - Statement of Rates
ITS-I and IHS Rates
v.9.0.0 Superseding v.8.0.0
Rate Schedule IHS
MILEAGE (n)
(Dth-Mile)
Max. Min.
(e) 0.000000
NON-MILEAGE (o)
(Dth)
Max, Min.
(e) 0.000000
DELIVERY (c)
(Dth-Mile)
Max. Min.
0.000016 0.000016
FUEL (d)
(Dth-Mile)
BASE
Ma"r. Min,
0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-l (Medford) (f)
0.005959 0.000000
COYOTE SPRINGS
E-3 (Coyote Springs) (i)
0.002770 0.000000
CARTY LATERAL
E-4 (Carty Lateral) (p)
0.010025
0.002772
0.000000 0.000026 0.000026
0.000000 0.000000 0.000000
0.359587 0.000000 0.000000 0.000000
SURCHARGES
ACA (k)(k) (k)
lssued: November 30, 2018
Effective: January 1,2019
Docket No. RPl9-370-000
Accepted: January 2, 2019
Exhibit E - Pipeline Tariff Sheets Page 6 of 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: November 30, 2018
Effective: January 1,2019
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v.l 7.0.0 Superseding v. I 6.0.0
Docket No. RPI 9-370-000
Accepted: January 2, 2019
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes:
(a) The mileage component shall be applied per pipeline mile to gas transported by GTN for
delivery to shipper based on the primary receipt and delivery points in Shipper's contract.
Consult GTN's system map in Section 3 for receipt and delivery point and milepost
designations.
(b) The non-mileage component is applied per Shipper's MDQ at Primary Point(s) of Delivery
on Mainline Facilities,
(c) The delivery rates are applied per pipeline mile to gas transported by GTN for delivery to
shipper based on distance of gas transported. Consult GTN's system map in Section 3 for
receipt and delivery point and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel, line loss, and other
utility purposes, plus other unaccounted-for gas used in the operation of GTN's combined
pipeline system in an amount equal to the sum of the current fuel and line loss percentage
and the fuel and line loss percentage surcharge in accordance with Section 6.38 of this
tariff, multiplied by the distance in pipeline miles transported from the receipt point to the
delivery point multiplied by the transportation quantities of gas received from Shipper
under these rate schedules. The current fuel and line loss percentage shall be adjusted each
month between the maximum rate of 0.0050% per Dth per pipeline mile and the minimum
rate of 0.0000% per Dth per mile. The fuel and line loss percentage surcharge is 0.0000%
per Dth per pipeline mile. No fuel use charges will be assessed for backhaul service.
Currently effective fuel charges may be found on GTN's Internet website under
"Informational Postings. "
(e) Seasonal recourse rates apply to short-term firm (STF) service under Rate Schedules FTS-I
and FHS (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 Schedules ITS-I and IHS. 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 ITS-1 and IHS service are as follows (delivery
charges and applicable surcharges continue to apply):
Exhibit E - Pipeline Tariff Sheets PageT oI 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
For STF and ITS-I:
PART 4,3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v. I 7.0.0 Superseding v. 1 6.0.0
Peak NM Res.
Peak Mi. Res.
Off-Pk NM Res.
Off:-Pk Mi. Res.
For IHS:
Peak NM Res.
Peak Mi. Res.
Off-PkNM Res
Off-Pk Mi. Res.
(0
(e)
(h)
Issued: November 30, 2018
Effective: January l, 2019
4 Peak
Mos.
$0.043336
$0.000s47
$0.024763
$0.000313
4 Peak
Mos.
$0.1 04006
$0.001313
$0.0s9431
$0.0007s 1
3 Peak
Mos.
s0.043336
$0.000s47
$0.026827
s0.000339
2Peak
Mos.
$0.043336
$0.000s47
$0.028478
$0.000360
I Peak
Mo.
$0.043336
s0.000s47
$0.029828
$0.000377
0 Peak
Mos.
$0.030954
$0.00039r
$0.030954
$0.00039r
3 Peak
Mos.
$0.r04006
$0.001313
$0.064385
$0.000814
2 Peak
Mos.
$0. r 04006
$0.001313
$0.068347
$0.000864
I Peak
Mo.
$0. l 04006
$0.001313
$0.071s87
$0.00090s
0 Peak
Mos.
$0.074290
$0.000938
90.074290
$0.000938
Months currently designated as "Peak Months" may be found on GTN's Internet website
under "lnformational Postings." By March I of each year, GTN will post the Peak Months
for the upcoming twelve-month period beginning June I of the same year.
Applicable to firm service on GTN's Medford Extension.
Reserved for Future Use.
E-2 (Diamond l) is aNegotiated Rate consisting of a reservation charge of $0.002972 per
Dth per day for the first 45,000 Dtl/d and E-2 (Diamond 2) is a Negotiated Rate consisting
of a reservation charge of $0.001 166 per Dth per day for the second 45,000 Dtt/d. During
leap years, E-2 (Diamond l) is a Negotiated Rate consisting of a reservation charge of
$0.002964 per Dth per day for the first 45,000 Dth/d and E-2 @iamond 2) is a Negotiated
Rate consisting of a reservation charge of $0.001 I 63 per Dth per day for the second 45,000
Dth/d. Pursuant to Article VI, Subsections B and C of the Amended Stipulation and
Agreement filed with the Commission on October 16, 2018, in Docket No. RP15-904-001,
and as accepted by Order of the Commission dated November 30,2018, the Diamond I and
Diamond 2 Negotiated Rates in Section 4.1, above, shall be modified as follows: l) from
January 1,2019, through December 31,2019, and January l,202l through December 31,
202l,the Diamond I reservation charge shall be $0.002823 and the Diamond 2 reservation
charge shall be $0.001108; 2) from January 1,2020, through December 31,2020, the
Diamond I reservation charge shall be $0.002816 and the Diamond 2 reservation charge
shall be $0.001105.
(i) Applicable to firm service on GTN's Coyote Springs Extension.
Docket No. RP I 9-370-000
Accepted: January 2, 2019
Page 8 ol 42Exhibit E - Pipeline Tariff Sheets
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: November 30, 2018
Effective: January 1,2019
PART 4.3
4.3 - Statement of Rates
Foo0rotes to Statement of Effective Rates and Charges
v.l 7.0.0 Superseding v. I 6.0.0
Docket No. RPI 9-370-000
Accepted: January 2,2A$
0) The Ovemrn Charge shall be equal to the rates and charges set forth for intemrptible service
under Rate Schedule ITS-1.
(k) In accordance with Section 6.22 of the Transportation General Terms and Conditions of this
FERC Gas Tariff, Fourth Revised Volume No. l -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) Reserved for Future Use.
(m) Reserved.
(n) The Rate Schedule ITS-1 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.
(p) Applicable to firm service on GTN's Cafi Lateral Extension.
Exhibit E - Pipeline Tariff Sheets Page 9 of 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.6
4.6 - Statement of Rates
Ne goti ated Rate Agreements;fir*ilJ:l,tl
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTTATED RATE AGREEMENTS UNDERRATE SCHEDULES FTS.I AND LFS-I
TERM OF
CONTRACT
tUvol -
t0l3U25
04101116 -
t0l3,/t6
RATE
SCHEDULE
FTS-I
DTFYD
20,000
PRIMARY
RECEIPT
POINT
PRIMARY
DELIVERY
POINT
RATE
12 13SHIPPER
Avista
Corporation /l
Powerex Corp./l
Mercuria Commodities 04/0 l/l 8
Canada Corporation ll 03131124
Avangrid Renewables, 06103101
LLC il 10131/25
FTS-I 20,000 Kingsgate Malin
FTS-I 60,000 Kingsgate Malin
FTS-I 80,000 Medford
Medford Medford Ext. l7
Meter
/5
l4
Klamath
Cogeneration
Docket No. RP I 9-530-000
Accepted: January 22, 2019
t6
Issued: December 31, 2018
Effective: January l, 2019
Exhibit E - Pipeline Tariff Sheets Page 10 ol 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: December 31, 2018
Effective: January l, 2019
PART 4.7
4.7 - Statement of Rates
Footnotes forNegotiated Rates - FTS-I and LFS-1
v.8.0.0 Superseding v.7.0.0
Docket No. RPI 9-530-000
Accepted: January 22,2019
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-l and LFS-l
/t This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
/2 Unless otherwise noted, all Shippers pay GTN's maximum Reservation Charge, Delivery
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
/3 Index Price References: Unless otherwise noted, references to "Daily Index Price" shall
mean the price survey midpoint for the specified point as published in Gas Daily for the
day of gas flow, Weekend and holiday prices will be determined using the next available
Gas Daily publication. Unless otherwise noted, the references to the "NGI FOM" for a
specified point shall mean Natural Gas Intelligence's First of Month Bid Week Survey
(Supplement to NGI's Weekly Gas Index) Spot Gas Price for the specified point.
14 a. GTN and Shipper have agreed to a fixed reservation reservation charge of $.2565 along
with applicable surcharges for all quantities on the Kingsgate to Malin path.
b. Effective the earlier of January l, 2022, or the termination of the Amended Settlement
in Docket No. RP15-904-001, the Rate Reduction shall expire and the negotiated rate shall
revert to $.27 along with applicable surcharges for all quantities on the Kingsgate to Malin
path.
15 GTN and Shipper have agreed to a Fixed Reservation Rate Charge of $0.26300 inclusive of
the mileage and non-mileage components, which shall be applicable to the Primary Receipt
and Delivery Points as well as secondary points, as follows:
Secondary Receipt Points: All points on GTN's system
Secondary Delivery Points: All points on GTN's system
In addition, Shipper shall pay all applicable charges and surcharges in accordance with
GTN's FERC Gas Tariff.
16 a. For the period January 1,2019, to December 31,2021, GTN and Shipper have agreed
that the negotiated rate shall be $0.085821 for the Monthly Reservation Charge for the
Initial Quantity set forth in Exhibit B of the agreement, and $0.033703 for the Monthly
Reservation Charge for the Option Quantity set forth in Exhibit B of the agreement along
with applicable surcharges.
Exhibit E - Pipeline Tariff Sheets Page 11 of 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-I and LFS-l
v.8.0.0 Superseding v.7.0.0
b. Effective the earlier of January 1, 2022, or the termination of the Amended Settlement
in Docket No. RP I 5-904-00 I , the rate reduction described in a., above, shall expire and the
negotiated rate shall revert to $0.090338 per dekatherm per mile for the Monthly
Reservation Charge for the Initial Quantity set forth in Exhibit B of the agreement, and
$0.035477 for the Monthly Reservation Charge for the Option Quantity set forth in Exhibit
B of the agreement along with applicable surcharges.
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
rul/0t-10/3U02
tt/t/02-t0l3t/03
tt/1/03-t0l3l/04
11lt/04-t0l3r/0s
tUt/05-t0Bua6
n/v06-1013U25
Percentage
75o/o
80%
85%
90%
95%
100%
The Daily Delivery Charge shall be equal to the 100% load factor equivalent of the FTS-I
E-2 rate, or its successor, and shall be multiplied by the positive difference between (a)
volumes delivered and (b) the contract MDQ times the appropriate Effective Period
Percentage.
Daily Delivery Charge = [Dth Delivered - (MDQ * Effective Period %)) * 100% Load
Factor Equivalent FTS-I E-2
/8 Reserved
/9 Reserved
ll0 Reserved
lll Reserved
/12 Reserved
ll3 Reserved
114 Reserved
/15 Reserved
Issued: December 31, 2018
Effective: January l, 2019
Docket No. RP19-530-000
Accepted: January 22,2019
Exhibit E - Pipeline Tariff Sheets Page 12 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised VolumeNo. l'A
/16 Reserved
ll7 Reserved
/18 Reserved
lssued: December 31, 2018
Effective: January l, 2019
PART4.7
4,7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-I and LFS-I
v.8.0.0 Superseding v.7.0,0
Docket No. RPl9-530-000
Accepted: January 22, 2019
Exhibit E - Pipeline Tariff Sheets Page 13 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.8
4.8 - Statement of Rates
Negotiated Rate Agreements - ITS-I and PAL
v.5.0.0 Superseding v.4.0.0
STATEMENT OF EFFECTIVE RATES AND C}I,ARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS.I AND PAL
SHIPPER
TERM OF
CONTRACT
PRIMARY
RECEIPT
POINT
PRIMARY
DELIVERY
POINT
RATE
SCHEDULE DTH/D
RATE
t2 t3
Issued: April24,2015
Effective: June 1,2015
Docket No. RPI 5-905-000
Accepted: May29,2015
Exhibit E - Pipeline Tariff Sheets Page 14 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised VolumeNo. l-A
Issued: April24,20l5
Effective: June 1,2015
PART 4.9
4.9 - Statement of Rates
Footnotes for Negotiated Rates - ITS-I and PAL
v.5.0.0 Superseding v.4.0.0
Docket No. RPl5-905-000
Accepted: May29,2015
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTI,ATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS.I AND PAL
Explanatory Footnotes forNegotiated Rates under Rate Schedule ITS-I and PAL
ll This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
/2 Unless otherwise noted, all Shippers pay GTN's maximum Mileage and Non-Mileage
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
/3 lndex 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.
Exhibit E - Pipeline Tariff Sheets Page 15 of 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
NON.CONFORMING SERVICE AGREEMENTS
PURSUANT TO $ 1s4.r r2(b)
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.4.0.0 Superseding v.3.0.0
Effective Termination
DateName of Shinper
Contract
Number
Rate
Schedule
Cascade Natural Gas CorPoration
Chevron USA [nc.
City of Burbank
IGI Resources, Inc.
Northern Califomia 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 Energr 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 Energr 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 Enerry Commodities
Group, Inc.
Enserco Energr Inc.
ConocoPhillips Company
UBS AG (London Branch)
152
ls3
154
158
r63
167
168
169
170
177
178
t'l9
180
181
182
2591
2857
2858
7828
8035
ll1
tt2
l19
144
146
4621
4721
4770
6759
'7047
7068
7804
7806
7807
7812
7816
FTS.I
FTS-I
FTS-1
FTS-1
FTS-1
FTS-I
FTS-I
FTS.I
FTS-I
FTS.I
FTS-1
FTS-I
FTS-I
FTS.I
FTS-I
FTS-I
FTS-I
FTS.I
FTS-I
FTS-I
ITS-I
ITS-I
ITS.I
ITS.I
ITS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-1
AIS-I
AIS.I
AIS-I
AIS-1
AIS-I
AIS.I
111y1993
11nil993
nlU1993
lvt/1993
111111993
tlll/1993
tUt/1993
t1llt1993
tUv1993
11/U1993
1uU1993
tuU1993
tl,lUt993
tUUt993
tvut993
8lUt995
tuUr99s
1UU1995
613D00t
luU200t
2lU1992
4lyt992
4t22/t992
7123/1993
8lyt993
121il1996
Utl1997
U25/1997
611',711999
4l10/2000
4/27/2000
s/30/2001
5/30/2001
5130/2001
sl30l200t
s/30/2001
t0l3t/2023
10131t2023
10131t2023
10131t2013
1013112023
10t31/2023
1013112023
1013y2023
1013U2023
r0t3v2023
1013v2023
1013112023
10131t2023
tol3U2023
t0/3112023
10t31/2025
t013u2025
1013U2025
1013U2025
t0l3r/2025
10131t2010
313112011
4l22t20tl
9t30/2010
8lU20t0
1213112010
t2/3UzAt0
1213112010
12131t2010
12t31/20r0
t2l4l20t9
t2l3U202t
t2l3U202t
t2/3u202r
12/3y2021
12131t2021
AIS.1
AIS-I
AIS-1
AIS-I
8l2D00t
1112712001
U8t2002
4ltr/2002
8t3u2021
t1/301202r
U3t/2022
4t3012023
Issued: September 25,2015
Effective: October 26, 2015
Docket No. RPI 5-1 294-000
Accepted: October 23, 2015
Exhibit E - Pipeline Tariff Sheets
8038
8176
8228
8318
Page 16 ol 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: September 25, 2015
Effective: October 26, 201 5
Exhibit E - Pipeline Tariff Sheets
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.4.0.0 Superseding v.3.0.0
Concord Energy LLC
Tenaska Marketing Ventures
Cargill, Inc.
Menill 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 Energy Marketing, LLC
Suncor Energy Marketing Inc.
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequent Energy Management LP
Occidental Enerry Marketing, Inc.
NextEra Energy Power Marketing, LLC
Natural Gas Exchange, Inc.
Citigroup Energy Inc.
IGI Resources, Inc.
Macquarie Cook Energy, 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 Califomia 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)
8421
85s9
8s94
8674
8670
8880
8887
9002
8978
9035
9r l5
9149
9281
9285
9530
9774
10197
10308
I 0336
10359
r0625
10639
10646
4576
4619
4720
4868
4908
s348
5677
5679
5837
5992
6226
6378
6613
7061
7798
7803
7805
78 l9
7820
7833
AIS-1
AIS.I
AIS-I
AIS.I
AIS-I
AIS.I
AIS-I
AIS.I
AIS.I
AIS-I
AIS-1
AIS.l
AIS.I
AIS-I
AIS.I
AIS.I
AIS.l
AIS-I
AIS-I
AIS.I
AIS-I
AIS-I
AIS-I
PS-I
PS-I
PS-l
PS.1
PS-1
PS-I
PS-r
PS-1
PS.I
PS-1
PS-I
PS-I
PS-1
PS-I
PS-I
PS-I
PS-I
PS-I
PS-I
PS-I
7/2212002
11112003
311912003
611312003
71U2003
t21U2003
12t1t2003
3A12004
313t2004
4t27t2004
711712004
811612004
r1t8t2004
t1/t512004
61U2005
10nt2005
712612006
1012712006
n/u2006
12122/2006
411012008
4129120A8
5/3012008
t2/Ut996
t2l1lt996
vUt997
3lyt991
315/1997
7131t997
1016n997
t0l7l199'7
,rt3fi997
2113fi998
5tr4fi998
812511998
1211411998
4/20t2000
sl30t200l
5/30t2001
513012001
s/30/2001
st30t200r
6/14t200t
713v20r2
12131t2012
313U2013
6n3t2023
6t30l2at3
11130/20t3
71U20fi
212812014
31312014
4130t2014
6130120t4
7/3U2014
10131/2014
t0l3u20t0
513u20t5
9t30t20t5
7125t20n
t0/3U20n
l013t/2010
12/3112010
4/30t2018
4130120t8
sl3U20t8
t2l3U20t0
12131t2010
t2l3t/2010
t2l3Ll20t0
t213U2010
t2l3U20ta
1213v2010
1213v2010
5lt7l20t0
t213v2023
t2l3U20t0
t2l3U20t0
12/3U2010
4120t2020
t2l3t/2021
t2/3v2021
12131/2021
t2l3U202t
t2l3t/2021
6/8t2020
8037
8229
8283
83 l6
PS.I
PS-I
PS.I
PS.I
81212001
U8/2002
3114t2002
41112002
813U2021
113t/2022
3t3112022
4t3012023
Docket No. RPI 5- 1 294-000
Accepted: October 23, 2015
Page 17 ot 42
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: September 25, 2015
Effective: October 26, 2015
PART 4.IO
4,10 - Statement of Rates
Non-Conforming Service Agreements
v.4.0.0 Superseding v.3.0.0
RWE Trading Americas Inc.
Fortis Energy Marketing & Trading GP
Concord Energy LLC
Select Natural Gas LLC
Tenaska Marketing Ventures
Cargill,Inc.
United Energy Trading, LLC
Apache Corporation
Occidental Energy Marketing, Inc.
Tenaska Marketing Ventures
Califomia Dept. of Water Resources
Devon Canada Marketing Corporation
Merrill Lynch Commodities, Inc.
Pacific Summit Energy LLC
Louis Dreyfus Enerry Canada LP
Louis Dreyfus Energy Services L.P.
Devlar Energy Marketing, LLC
Suncor Energy Marketing Inc,
J.P. Morgan Ventures Energy Corporation
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequenl Energy Management LP
El Paso Ruby Holding Company, LLC
Portland General Electric Company
8324
8340
8406
8534
8539
8595
8652
8668
8784
8873
8886
8923
9018
9173
9263
9273
9584
9772
9948
10r95
10310
10332
12071
17293
PS-I
PS-l
PS-I
PS-l
PS-I
PS-1
PS-I
PS.1
PS-1
PS-l
PS-I
PS-1
PS.I
PS-I
PS-I
PS-1
PS.I
PS-I
PS-I
PS-I
PS-1
PS-l
FTS.I
FTS-1
4t16t2002
51212002
7t2212002
r11t5t2002
tzll12002
3n9t2003
5/2312003
71112003
9fi0t2003
t2/U2003
t2^t2003
21U2004
4/7n004
8130t2004
10129t2004
1U412004
5121200s
tol1t200s
21U2006
7126t2006
1012712006
111112006
rt/1t2012
t013U20t5
4130t2022
513y2022
7/3v2012
tot31t2012
ty30l20t2
313v2013
5l3ll20t3
6130/2013
813U2013
n130/2013
7lU20tl
v3U20t4
417t20t4
8/30/2010
rDt31/2010
tol3l/20t4
4130/2015
913012015
U3v20t6
7t2st20tt
r0l31t20tt
l0l3U201r
313v2018
10131t204s
Docket No. RP I 5- I 294-000
Accepted: October 23, 2015
Exhibit E - Pipeline Tariff Sheets Page 18 ot 42
Northwcst Pipeline LLC
FERC Gas Toriff
Fifth Revlsed Volume No. I
BaseTariff Rate(1), (3)
Minimum Maximum
Ninth Revised Sheet No. 5
Superseding
Eighth Revised Sheet No. 5
STATEMENT OF RATESEffective Rates Applicable to
Rate Schedules TF-l, TF-z, TI-l-, TFL-I and TIL-I(Dollars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule TF-1 (4) (5)
Reservation(Large Customer)
System-Wide
25 Year Evergreen Exp
Volumetric t2l(Large Customer)
System-Wide
25 Year Evergreen Exp.
(Sma11 Customer) (6)
Scheduled Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Da1ly Overrun
Annual overrun
Rate Schedule TI-1 (2\
VolumeEric (7)
Rate Schedule TFL-1 (4) (5)
ReservationVolumetric (21
Scheduled Overrun (21
Rate Schedule TIL-1 (2)
Volumetric
.00000
.00000
. 008 32
. 008 32
. 008 32
. 008 32
.39033
.32039
. 008 32
. 008 32
.69421
.39865
.00000
. 008 32
. 008 32
. 008 32
39033
00832
39865
3986s
.00832 . 39865
Exhibit E - Pipeline Tariff Sheets Page 19 oI 42
I
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Third Revised Shcct No. 5-A
Superseding
Second Revised Sheet No.5-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TE-2t TI-1, TFL-1 and TIL-L (Continued)
(Dollars per Dth)
Entitlement Unauthorized Overrun and Underrun (B) Rate
General SysEem Unauthorized DaiIy Overrun (9)
General System Unauthorized DaiIy Underrun 10.00000
General System Unauthorized Underrun Imbalances
not eliminated after 72 hours 10.00000
Customer-Specific Entitlement Penalty 10.00000
Footnotes
1
2
Rate excludes surcharges approved by the Commission.
Annual Charge Adjustment ("ACA") surcharge may be applicable. Section
16 of the General Terms and Conditions describes the basis and
appl-icability of the ACA surcharge.
Exhibit E - Pipeline Tariff Sheets Page 20 ol 42
Northwcst Pipeline LLC
FERC Gos Tariff
Fifth Revised Volume No. I
Thirteenth Revised Sheet No. 5-B
Superseding
Twelfth Revised Sheet No. 5.B
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TE-2, TI-1/ TFL-1 and TIL-1 (Continued)
Footnotes (Continued)
(3) To the extent Transporter discounts the Maximum Base Tariff Rate, such
discounts wiIl be applj.ed on a non-discriminator:y basis, subject to the
policies of Order No. 491.
Shippers receiving service under these rate scheduLes are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No,
t4.
An incremental facilities charge or other payment method provided for
in SecEion 2L or 29 of the General Terms and Conditions, is payable in
addltion to all other rates and charges if such a charge is included in
Exhibit C to a Shlpper's Transportation Service Agreement.
In addj.tion to the rates set forth on Sheet No, 5, Puget Sound Energy,Inc.'s Transportation Service Agreement No. 140053 is subject to an
annual incremental facility charge pursuant to Section 21 of the
General Terms and Conditions for the South Seattle Delivery Lateral
Expansion Project. The effective annual incremental faci11t,y charge is
$3,097,543 and is billed in equal monthly one-twelfth increments. Thedaily incremental facility charge is $0.13281 per Dth.
In addition to Ehe reservation rates shown on Sheet No. 5, Shippers who
contract for Columbia Gorge Expansion Project capacity are subject to a
facility reservation surcharge pursuant to Section 3.4 of Rate Schedule
TF-1. The facility charge used in deriving the Columbia Gorge Expansion
Project facility reservation surcharge has a minimum rate of $0 and a
maximum rate during the indicated months or calendar years as follows:
(DoIlars per Dth)
Year
20L8
20t9
2020
Rate
s0.0985s
$0.09189
$0.08667
Year Rate2o2L S0.081942022 S0. 07 696
Year
2023
2024
Rate
$0.07199
$0.06680
January L,2025 - March 31, 2025 90.06552
Exhibit E - Pipeline Tariff Sheets Page 21 ol 42
Northwest Pipeline LLC
FERC Ges Trrlff
Fifth Revised Volume No. I
Seventh Revised Sheet No. 5-C
Superseding
Sixth Revised Sheet No. 5-C
STATEMENT OF RATES (Continued)
Effective Rates AppLicable to
Rate Schedules TE-1, TF-2' TI-1, tFL-1 and TIL-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(4) A11 reservation rates are daily rates computed on the basis of 365 daysper year, except that such rates for leap years are computed on the
basis of 366 days.
For RaEe Schedule TF-1, the 25-Year Evergreen Expansion reservation and
volumetric rates apply to Shippers receiving service under Rate
Schedule TF-1 Evergreen Expansj-on service agreements. The Syst,em-Wide
reservatj-on and volumetric rates apply to Shippers receiving service
under all other Rate Schedule TF-1 service agreements.
For Rate Schedule TF-1, the 2S-Year Evergreen Expansion maximum basetarlff reservation rate is comprised of S0.31603 for transrnission costs
and $0.00435 for storage costs. The System-Wide maximun base tariff
reservation rate for Rate Schedule TE-1 and the maximum base tariff
reservation rate for Rate Schedule TF-2 are comprised of $0.38597 for
transmission costs and $0.00436 for storage costs.
Eor Rate Schedule TF-1 (Large Customer), the maximum base tariff
volumetric rates applicable to Shippers receiving service under Rate
Schedule TF-1 Evergreen Expansion service agreements are comprised of
$0.00806 for transmission costs and $0.00026 for storage costs. The
maxi.mum base tariff volumetric rates for all other services under Rate
Schedule TF-1 (Large Customer) and for services under Rate Schedule TF-2 are comprised of $0.00806 for transmission costs and $0.00026 for
storage costs.
Exhibit E - Pipeline Tariff Sheets Page22 ol 42
Northwcst Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Eighth Revised Sheet No. 5-D
Superseding
Seventh Revised Sheet No. 5-D
STATEMENT OF RATES (CONtiNuCd)
Effective Rates Applicable to
Rate SChedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(5) Rates for Rate Schedules TF-1r TF-2 and TFL-1 are afso applicable to
capacit,y release service except for short-term capacity release
transactions for a term of one year or less that take effect on or
before one year from the date on which Transporter is notifi-ed of the
release, which are not subject to the stated Maximum Base Tarj-ff Rate.
(Section 22 of the General- Terms and Conditions describes how bids for
capacity release wi.Il be evaluated. ) The reservation rate is the
comparable volumetric bid reservation charge applicable to Replacement
Shippers bidding for capacity released on a one-part volumetric bj.d
basls.
(6)For Rate Schedule TF-1 (Small Customer), the Maximum Base Tariff Rate
is comprised of $0.68529 for transmission costs and $0.00898 for
storage costs. Transporter will not schedule gas for delivery to a
Sma1l Customer subiect to this Rate Schedule TF-1 under any
transportation Service Agreement (excluding its Rate Schedule TF-2
Service Agreement at Plymouth held at the time of storage service
unbundting in RP93-5) unless such Small Customer has scheduled its fulI
Contract Demand for firm service under its Rate Schedule TF-1 (SmaIl
Customer) Service Agreement(s)for that day.
(?) Rate Schedule TI-1 maximum base tariff volumetric rate is comprised of
$0.39403 for transmission costs and $0.00462 for storage costs.
TIL-1 pursuant(8)Appllcable to Rate Schedules TF-1, TF-2, TI-1, TFL-1 and
to Section 15.5 of the General Terms and Conditions.
(e)The General System Unauthorized Daily Overrun Charge per Dth is thegreater of 910 or 150 percent of the highest midpoint price at NW Wyo.
Poo1, NW s. of Green Ri-ver, Stanfield Ore., NW Can. Bdr. (Sumas), Kern
River Opal, or El Paso Bondad as reflected in the Daily Price Survey
published in "Gas Daily."
Exhibit E - Pipeline Tariff Sheets Page 23 oI 42
Northwest Pipeline LLC
FERC Gas Teriff
Fifth Revised Volume No. I
Sirth Revised Sheet No. 6
Supcrseding
Fifth Revised Sheet No.6
STATEMENT OF RATES (Continued)
EffecEive Rates Applicable to Rate Schedules DEx-l and PAL
(Dol1ars per Dth)
Type of Rate
BaseTariff Rate (1),(3)
Minimum Maximum
Rate Schedule DEX-I (2ll, (4)
Deferred Exchange .00000 .39865
Rate Schedule PAL
Park and Loan .00000 .3986s
Footnote s
(1) Rate excludes surcharges approved by the Commission.(2) ACA surcharge may be applicable. Section 16 of the General Terms andConditions describes the basis and applicability of the ACA surcharge,
(3) To the extent Transporter discounts the maximurn current.ly effectivetariff rate, such discounts will be applied on a non-discriminatorybasis, subject to the polici,es of Order No. 497.
(4) Shippers receiving service under this rate schedule are required tofurnish fuel reimbursement in-kind at the rates specified on Sheet No.14, excepL as provided in Section 4 of Rate Schedule DEx-1.
Exhibit E - Pipeline Tariff Sheets Page 24 ot 42
Northwest Pipeline LLC
FERC Ges Tariff
Fifth Revised Volume No. I
Seventh Revised Sheet No. 7
Superseding
Sixth Revised Sheet No. 7
STATEMENT OF RATES (Contlnued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
Rare Schedule sGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Capacity Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper
Expansion Shipper
storage Charge
Pre-Expansion Shipper
Expansion Shipper
Base
Tariff Rate (1)
Mi-nimum Maximum
0.00000
0.00000
0.00000
0.00000
0.00000
0.00000
0.00000
0.00000
0.01562
0.04056
0.00057
0.00348
0.01562
0.04056
0.00057
0.00348
Rate Schedule SGS-2I
Volumetric 0. 00000 0.00224
Footnotes(1) Shippers receiving service under these rate schedules are required tofurnish fuel reimbursement in-kind at the rates specified on SheetNo. 14.
Exhibit E - Pipeline Tariff Sheets Page25 of 42
Northwcst Pipeline LLC
FERC Gas Teriff
Fifth Revised Volume No. I
Tbird Revised Sheet No. 7-A
Supcrseding
Second Revised Sheet No. 7-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-28 and SGS-2I (Continued)
Footnotes (Continued)
(21 Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days
Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter J-s
notified of the release, which are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
describes how blds for capacity release will be evaluated. ) The
Withdrawal Charge and Storage Charge are applicable to Replacement
Shi-ppers bidding for capacity released on a one-part volumetri-c bid
basis.
Exhibit E - Pipeline Tariff Sheets Page 26 ot 42
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
RESERVED FOR EUTURE USE
Eighth Revised Sheet No. 8
Superseding
Seventb Revised Sheet No. 8
Exhibit E - Pipeline Tariff Sheets Page27 ol42
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volurne No. I
Seventh Revised Sheet No. 8-A
Supcrsedlng
Sirth Revised Sheet No. 8-A
STATEMENT OF RATES (Continued)
Effect.ive Rates Applicable to Rate Schedules LS-2F and LS-2I
(DoIlars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate (1)
Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (21 0.00000
0.00000
0 .02581
0.00331Capacity Demand Charge (2')
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage CapacitY Charge 12\
0.00000
0.00000
0.02587
0.0033r
Liquefact ion
Vapori zation
0.90855
0.03386
0. 9085s
0.03386
Rate Schedule LS-2I
Volumetric 0. 00000 0.00662
Liquefaction
Vapori zation
0.90855
0.03385
0. 9085s
0.03386
Footnotes
(1) Shlppers receiving service under these rate schedules are requiredfurnish fuel reimbursement in-klnd at the rates specified on Sheet
L4.
to
No
t2t Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are cornputed on the basis of 365 days
(3)Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or less that
take effect on or before one year from the daEe on which Transporter is
notified of the release, whlch are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
describes how bids for capacj-ty release will be evaluated. ) TheVaporization Demand-Related Charge and Storage Capacity Charge are
applicable to Replacement Shippers bidding for capacity released on aone-part volumetrlc bid basis,
Exhibit E - Pipeline Tariff Sheets Page28 oI 42
Northwert Pipeline LLC
FERC Gas Teriff
Fifth Revised Volume No. I
Fifth Revised Sheet No. 9
Superseding
Fourth Revised Sheet No. 9
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-3F and LD-4I
(DolIars per Dth)
Rate Schedul-e and
Type of Rate
Rate Schedule LS-3F (3)
Demand Charge (21
Capacity Demand Charge (2\
Vol-umetric Bid Rates
Vaporization Demand-Related Charge (21
Storage Capacity Charge (21
Liquefaction Charge (4)
Vaporization Charge
Rate Schedule LD-4I
Volumetric Charge
Liguefactlon Charge (4)
Base
Tariff Rate (1)
Minimum Maximum
0.00000
0.00000
0.00000
0.00000
0.908s5
0.03386
0.00000
0.90855
0.02587
0 .00331
0 .0258'7
0.00331
0.90855
0.03386
881 2
0855
0.7
0.9
Footnotes
(1) Shippers receiving service under these rate schedules are required tofurnish fuel reimbursement in-klnd at the rates specified on Sheet No.
14.
(2)Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or tess thattake effect on or before one year from the date on which Transporter is
noEified of the release, whlch are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the ceneral Terms and Conditionsdescribes how bids for capacity release will- be evaluated. ) TheVaporization Demand-Related Charge and Storage Capacity Charge areappli.cable to Replacement Shippers biddlng for capacity released on aone-part volumetric bid basis.
(3)
(4)The Liquefaction Charge wilI be trued-up annually pursuant to Section
14.20 of the General Terms and Conditions.
Exhibit E - Pipeline Tariff Sheets Page29 oI 42
Northwest Pipeline LLC
FERC Gas Tariff
tr'ifth Revised Volume No. I
RESERVED FOR FUTURE USE
First Revised Sheet No. l0
Superseding
Substitute Original Sheet Nos. 10 through 13
Exhibit E - Pipeline Tariff Sheets Page 30 of 42
Northwest Pipeline LLC
FERC Gas Teriff
Fifth Revised Volume No. I
Ttventy-Fourth Revlsed Sheet No. 14
Superseding
Twenty-Third Revised Sheet No. l4
1.64t
0. 50t
Rate Schedules TF-1 | TF-2, TI-1, and DEX-1
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1)
Rate Schedule TFL-1
Rate Schedule TIL-1
Rate Schedules SGS-2F and SGS-2I
Rate Schedules LS-2E, LS-3F and LS-2I
Liquefact ion
Vapori zation
Rate Schedule LD-4I
Li-quef act ion
STATEMENT OF FUEL USE REQUIREMENTS EACTORS
FOR RETMBURSEMENT OE FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained in t.his Tariff, Fifth Revised Volume No. 1
The rates set forth on Sheet Nos, 5, 6,1,8 and 8-A are exclusive of
fuel use requirements. Shipper shal1 reimburse Transporter in-kind for its
fuel use requirements in accordance with Section 14 of the General- Terms and
Conditions contained herein.
The fuel use reimbursement furnished by Shippers shal1 be as follows
for the applicable Rate Schedules included 1n this Tariff:
0 .242
0.988
0. 533
0. 98r
The fuel use factors set forth above shall be calculated and adjusted
as explained in Section 14 of the General ?erms and Conditions. Fuel
reimbursement quantit.ies to be supplied by Shippers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nominated for recelpt by Transporter from Shipper for transportation,
Jackson Prairie injection, Plymouth Iiquefaction, Plymouth vaporization, orfor deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge wilI apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific Pool recej.pt points under
Evergreen Expansion service agreements.
Exhibit E - Pipeline Tariff Sheets Page31 ol 42
6111t2019
Receipt Services
FT-RAverage Demand Rato (3 yr term) 1
lT.R (l nterruptible Receipt)
Dellvery Servlces
ff{ Demand Rate (1 yrterm) 2
Group 1:
Empress/McNeill Border
Alberta-B.C. Border
Gordondale Border/Boundary Lk Border
ATCO: ClairmonUShell Croek/Edson
Group 2:
AllGroup 2 delivery points
Group 3:
All Group 3 delivery points
[!Q (lntenuptible Delivery)
Group 1:
EmpresdMcNeill Border
Alberta-B.C. Border
Gordondale Border / Boundary Lk Border
ATCO; ClairmonUShell CreeUEdson
Group 2:
All Group 2 delivery points
Exhibit E - Pipeline Tariff Sheets
www.tccustomerexprees.com/2766.htm l?pri nt-yes
NGTL System
() rc Enersy Customer Express
NGTL System
TransCanada's - NGTL System Transportation Rates & Abandonment Surcharge
2019 Final Rates - Effective May 1,2019
ErclntSld-bllySil:nnsportatlon Rans below do notln er-
Tarlff Rate
$/l0m'(Gdn)
210,741mo
7.97Id
Tarlff Rate
3cJ (Cdn)
lnformatlon Purposes
$/GJ/d (cdn) flMcf/d (cdn) f/MMBtuld (US)
18.3 19.6 15,0
21.1 22.6 17.3
lnformatlon Purposes
lrcJrd (Gdn) fltcf/d (Gdn) l,tMBturd (UE)
5.7glmo
5.48/mo
5.48/mo
5.48/mo
5.48/mo
6.58/mo
18.0
21.6
20.94
19.82
19.82
19.82
20.4
19.3
19.3
19.3
19.3
23.2
22.42
2'.t.22
21.22
21.22
19.0
18.0
18,0
18.0
1s,6
14.7
14.7
14.7
14.7
17.7
17.1
16.2
16.2
16.2
19.82 21.22
Page 32 ol 42
16.2
113
6111t2019 NGTL System
lFind ,ore details on Receipt Price Points at Receipl&i4l8Algg
'1-2 year lerm: 105% (Price Point C)
34 yearlerm: '100% (Price Polnt B)
5+ lrear term: 95% (Price Point A)
2 Find rnor" details on Delivery Price Points at Dgllygyfgh!-Bglgg
1-2 year term: 100% (Price Point Z)
3-4 yeat term: 9506 (Price Point Y)
5+ year torm: 90% (Price Point X)
- Aggr€gate charges for service will be determined in accordance with the NGTL System tariff and as such, shall include tha applicable
abandonment surcharge(s).
- Rates are payable in Canadian dollars.
- For bllling purposes,lOrmt units are used to Rocelpt Services and GJ units are for Delivery services
- Mcf and MMBtu units are provided for illustrative purposes only.
- Conversion factors below have been used to calculate tha rater provided for information purposos:
Cdn$/US$ 1 .29 - subjed to change (updated Sep 25, 2018)
6/GJ to C/MMBtu 1.06
$/10mr to 0/GJ 37.8 MJ/mt
- Actual heating value is dependent upon speciffc receipt or delivery points and ranges from 36.0 MJ/m3 to 44.0 MJlm3.
- Rates do not indude GST.
- FT-R rate rang€:
FT-R Rate Range $/103m3 ilGJld i,lMdld l/MMBtu/d
FT-R Celllng Rate 296.641mo 25.8 27.6 21.1
FT-R Floor Rate 124.841mo 10.9 11.6 8.9
201 9 Aba ndonment Surcha rges - Effective Janua ry 1, 2019
Abandonment surcharges arc ln addltbn to adlcable rccelpt and delVery tansporbtlon rates,
Abandonment Surcharges Tariff Rate lnformatlon Purposes
0/l0rmr (Cdn) 3/GJ(Cdn) UMcf (Cdn)
Monthly Abandonment Surcharge '10.90/mo 0.29/mo 0.31/mo
Daily Abandonment Surcharge 0.36/d 0.0095/d 0.01/d
- The services to which abandonment surcharges apply are denoted on the NGTL Tariff Table of Rates, Tolls and Charges.
Other information for TransCanada's NGTL System:
Gurrent
Receip[leinlffslg
Fuel Rates
AB Border Heat Values
Exhibit E - Pipeline Tariff Sheets
www.tccustomerexpress.com/2766.htm l?print=yes
Archives
ReceipllPqlolBales
Fuel Rates (2004 - 2010) (22 KB, XLS)
Fuel Rates (2000 - 2004) (41 KB, DOC)
Page 33 of 42
2t3
6t11t2019
Deliverv Point Ratos
NGTL System
AB Border Heat Values (61 KB, PDF)
Dlsclaimer:
The pricing and tolls information included on this website is intended to be used for planning purposes only and although
TransCanada endeavours to maintain the information in such a way that is accurate and current, it may not provide
accurate results. Use of this information is at user's sole risk and TransCanada shall not be Iiabte for user's use or
reliance on any results obtained from it.
Customer Express Home r Pricing & Tolls e NGTL System
Copyright @ 2019 TransCanada PipeLines Limited
Exhibit E - Pipeline Tariff Sheets
www.tccustomerexpress.com/2766.htm1?print=yes
Page 34 of 42
3t3
6t11t2019 Foothllls System - BC
() rc Enersy Customer Express
Foothills System - BC
Transcanada's Foothills BC Transportation Rates & Abandonment Surcharges
2019 Rates EffectlveJanuary 1,2019
fnnsporfrtbn Retcs btlow do notlnclude applicable Abandurmcnt Surcinrges
Service Tariff Rate lnformatlon Purposes
ABrBC to Klngegate
itc.tld ifficltd #ilmbturd
(cdn) (cdn) (Us)
l/GJ/km(Cdn)
51 Firm Servlce - Zone 8
FT Rate 0.0163193182(Monthly)
If Intemrptible Servlce -
Zone I
lT Rate 0.0005901781(Daily)
9.2 9.8 7.4
10.1 10.8 8.1
Aggregate charges for service will be determined in accordance with the Foothills Pipe Lines Gas Transportation Tariff
and as such, shall include the applicable abandonment surcharge(s)
201 9 Aba ndon ment Surcharges Effective Ja nua ry 1, 2019
Abandonmqrt surcharg* arc ln eddlflon to appllctble Tnnsp*1r,llon Rctes.
Abandonment Surcharges Tariff Rate
lnformatlon Purposes
All Tranrportatlon Servlccs
ryGJ ileJ f,rrrct
(Cdn) (Gdn) (Cdn)
$lMMbtu
0.1250196175(Monthly) 12.5 13.4 10.1
Monthly Abandonmcnt Surcharge
Dally Abandonment Surcharge 0.0041102340(Daily) 0.41 0.u 0.33
The services to which abandonment surcharges apply are denoted on the Foothills Pipe Lines Table of Effective Rates
1. For information purposes, the maximum Shippe/s Haul Distance used in the Shippe/s monthly charge for Service
calculaUon is 170.7 km.
Exhibit E - Pipeline Tariff Sheets Page 35 of 42
www.tccustomerexpress.oom2T6S.htrnl?print=yes
(us)
1t2
Arun11g Foolhills System - BC
2. Rates are payable in Canadian dollars and GJ units are us6d for billing purposes. Mcf and MMbtu units are provided
for information purposes only.
3. Conversion Factors below have been used to calculate the rates provided for information purposes:
Cdn$/US$ 1.3108- subject to change (updated Oct 26, 2016)
S/GJ to 0/MMBtu x 1.055056
S,IGJ lo $tUcf at a heat value of 37.8 MJ/m3
4. All rates are based on 1 00 per cent load factor utilization. The lT rate is 1 10 per cent of the FT rate.
5. Rates do not include G.S.T.
6. lnquiries regarding the BC System may be directed to:
Ashley Stowkorivy
Phone: [phone]
Emai I : ashlsy-SlgwBslsy@lrc0ssAlada.c@
Andrea Watters
Phone: [phone]
Email: andrea [e-mail]
Other information for TransCanada's Foothills (BC) System:
Current Archives
Fuel Rates and Heating-!&lues Heating Values
AB Border Heat Values AB Border Heat Values (61 KB, PDF)
Disslaimer:
The pricing and tolls information included on this website is intended to be used for planning purposos only and although
TransCanada endeavours to maintain the information in such a way that is accurate and current, it may not provide
accurate results. Use of this information is at user's sole risk and TransCanada shall not be liable for user's use or
reliance on any results obtained from it.
Customer Exprass Home r Pricing & Tolls r Foothllls System. BC
Copyright @ 2019 TransCanada PipeLines Limited
Exhibit E - Pipeline Tariff Sheets
wwwtccustomerexpress. com/2768. htm l? print=yes
Page 36 of 42
2t2
Tuscarora Gas Transmission Company
FERC Gas Tariff
Second Revised Volume No. I
Issued: March 15,2019
Effective: February 1,2019
Exhibit E - Pipeline Tariff Sheets
PART 4.I
4.1 - Statementof Rates
FT and LFS Rates
v.8. 1.0 Superseding v.8.0.0
ReservationCharge (Maximum)
(Minimum)
DeliveryCharge (Maximum)
(Minimum)
Authorized Ovemrn Charge (Maximum)
(Minimum)
Annual Charge Adjustment
Measurement Variance Gas Factor
RATE SCHEDULES FT And LFS
CURRENTLY EFFECTIVE RATES I/
(Maximum)
(Minimum)
$ 8.2194
$ 0.0000
$ 0.2733
$ 0.0030
2t
2.0%
(2.0%)
Docket No. RPI 9-419-00 I
Accepted: May2,2019
Page37 ol42
0.
0.
$
$
0030
0030
Volumetric Reservation Charge for Capacity Release $ 0.2733 3t
U For scheduling, imbalance and unauthorized ovenun charges see General Terms and
Conditions, Section 6.6. Maximum and minimum rates are applicable to backhaul
service.
2/ The Annual Charge Adjustrnent (ACA) is in addition to the above Delivery Charge and
the Authorized Ovem"rn Charge. The currently effective ACA unit charge as published
on the Commission's website (www.ferc.gov) is incorporated herein by reference.
3l The Maximum Rate does not apply to capacity release transactions of one (l) year or
less.
Page 8.1
Effective Date: April 1,2014
Page 38 of 42
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
TRANSPORTATION SERVICE . SOUTHERN
DEFINITIONS
APPLICATION
3.
ln this Toll Schedule, the following term shall have the following meaning:
(a),'@'meanSTran6portationService-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)..@,mean8thepointontheinternationalboundarybetween
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)'Sggy!gg-@' means in respect of each Firm Transportation Service - Southern
specified in a Firm Service Agreement, the term of each such Firm Transportation
Service - Southern as determined in accordance with Section 3.
All other terms used in this Toll Schedule shall have the same meaning as set forth in the
General Terms and Conditions.
2.This Toll Schedule applies to all Firm Transportation Service - Southern, AOS and
lntem.rptible Transportation Service - Southem, including lmport Backhaul Seryice, provided
by Westcoast on facilities in Zone 4 under the provisions of a Firm SeMce Agreement or an
lntenuptible Service Agreement into which the General Terms and Conditions and this Toll
Schedule are incorporated by reference.
For all purposes of this Toll Schedule, the Demand Toll applicable to any Firm
Transportation Service - Southem 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:
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 seMce as of
November 1, 2005;
in the case of each Firm Transportation Service - Southem 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;
in the case of each such Firm Transportation Service - Southem which is renewed
by a Shipper after November 1, 2005 in accordance with Section 2.06 of the
(a)
(b)
(c)
Exhibit E - Pipeline Tariff Sheets
Page 8.2
Effective Date: April 1,2014
Page 39 of 42
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
4.
General Terms and Conditions, the number of whole years in the renewal term of
each such seMce, 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 euch extension,
MONTHLY BILL. FIRM TRANSPORTATION SERVICE. SOUTHERN
Tha 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 - Southem specified in the Firm Service Agreement by the applicable
Demand Toll specified in Appendix A for Firm Transportation Service - Southem; and
(b)the amount of tiax on fuel gas coneumsd in operations payable under the Motor Fuel
Tax Ac.t (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 Tarms and Conditions.
MONTHLY BILL . AOS, INTERRUPTIBLE TRANSPORTATION SERVICE . SOUTHERN AND
IMPORT BACKHAUL SERVICE
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 lnteruptible Transportation
Service, other than lmport Backhaul Service, at that Delivery Point or at any other Delivery
Point in Zone 4, then, notwithstanding the provisions of the General Terms and Conditions
and for the sole purpose of determining the amount of the Commodity Tolls payable by
Shipper in accordance with this Toll Schedule for AOS and lnterruptible Transportation
Service - Southern, the following rules shall apply:
(a) firstly, in the case where Shipper would othenrise incur tolls on such day for AOS
and lntenuptible 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 SeMce at such Delivery Point;
(b) secondly, in the case where a Delivery Point at wtrich 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)
5.
Exhibit E - Pipeline Tariff Sheets
Page 8.3
Effective Date: April 1,2014
Page 40 of 42
Westcoast Energy lnc.
TOLL SCHEDULES - SERVICE
o.
(c)
of the 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 othenrise incur tolls for AOS and lntenuptible Transportation Service -
Southem;
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
fourthly, if Shipper has any remaining volume of unutilized Firm Transportation
Service - Southem 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 othenrise incur tolls for AOS and
lntenuptible Transportation Service - Southern.
(d)
The amount payable by a Shipper to Westcoast in rospect of AOS, lnterruptible
Transportation SeMce - Southern, and lmport Backhaul SeMce provided on each day in a
month shall be an amount equalto the sum of:
(a)the product obtained by multiplying the applicable Commodity Toll specified in
Appendix A for AOS, lnterruptible Transportation Service - Southern and lmport
Backhaul Service, respectively, by the Receipt Volume for such AOS or lnterruptible
Transportation Service - Southern (as determined after applying the rules set out in
Section 5) or for such lmport Backhaul Service, respectively, at the point from which
the residue gas is sourced, which is thermally equivalent to the volume of residue
gas (i) delivered to or for the account of Shipper at the Delivery Point, or (ii)
transmitted through Zona 4 for the account of Shipper on each such day during the
month;
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
the amount of tax on fuel gas consumed in operataons 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.
(b)
(c)
Exhibit E - Pipeline Tariff Sheets
Page 8,4
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
Flrm Transportation Seruice - Southern
Year Round Service
APPENDIX A
DEIUAND AND COMMODITY TOLLS
TRANSPORTATION SERVICE - SOUTHERN
Demand Tolls
g/103m3ho.
PNG
Delivery Point
lnland
Delivery Area
Huntingdon
Delivery Area
FortisBC
Kin$vale to
Huntingdon'Service Term
l year 149.61 368.52 660,39 291.87
2 years 145.25 357.79 641.15 283.36
3 years 140.90 347.05 621.92 274.ffi
4 years 139.4 343.47 615.50 272.03
5 years or more 137.99 339.90 609.09 269.20
' For Firm Transportation Service - Southern provided by Westcoast pursuant to a Firm Service Agreement
dated April 15, 2002 between Westcoast and FortisBC Energy lnc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
Winter Firm Service
Demand Tolls
$/103m3/mo.
Huntingdon Delivery Area
Service Term
WF Service
Novemberto March
1 yeil 990.59 660.39
2 years 961.73 641.15
3 years 932.88 621.92
4 years 923.25 615.50
5 years or more 913.64 609.09
' WF Service which has bEen designated as Revertible WF Service pursuant to Section 23.10 of the
General Terms and Conditions - Service to provide for firm transmission of residue gas in Zone 4 all days
of the year.
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.
Revertible WF
Service'
Effective Date: April 1,2019
Page 41 of 42Exhibit E - Pipeline Tariff Sheets
Page 8.5
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
AOS and lntemrptible Transportation Service - Southern
Commoditv Tolls
$/103;3
PNG lnland
Delivery Area
Huntingdon
Delivery Area
FortisBC
Kingsvale to
HuntirEdon'Months Point
Aprilto Octob€r 4.896 12.061 23.774 9.552
November to March 6,528 16.081 23.774 12.736
* 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.
lmport BackhaulSeryice
Commoditv Tolls
$/103;3
lnland
Delirory Area
PNG
Delivery Point
Compressor
Station No. 2
April to October
November to March
18.878
't7.246
23.774
23.774
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, 2019
Page 42 oI 42Exhibit E - Pipeline Tariff Sheets
Months
11.713
7.693