20170901Application.pdf

Avista Corp.
l4l I East Mission P.O.Box 3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
{,rutsrfr
Corp,
if -\
August 30,2017
State of Idaho
Idaho Public Utilities Commission
472 W. Washinglon Street
Boise, Idaho 837 02-5983
Case No. AVU-G-I7-0 4 /Advice No. l7-03-G
Attention: Ms. Diane Hanian
I.P.U.C. No. 27 - Natural Gas Service
Enclosed for electric filing with the Commission are the following revised tariffsheets:
Twenty-Fourth Revision Sheet 150 canceling Twenty-Third Revision Sheet 150
Nineteenth Revision Sheet 155 canceling Eighteenth Revision Sheet 155
The Company requests that the proposed tariff sheets be made effective November 1,2017 .
These tariff sheets reflect the Company's annual Purchased Gas Cost Adjustment ("PGA"). If
approved, the Company's annual revenue will decrease by approximately $1.7 million or
approximately 2.7Yo. 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 commercial customer using an average
of61 thermspermonthwillsee decrease of $l.23permonth,orapproximately2.4%o. Thepresent
bill for 61 therms is $51.10 while the proposed bill is $49.87. The Company will issue a notice to its
customers through a bill insert in the September 2017 to October 2017 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 Patrick Ehrbar at [phone] or
Annette Brandon at [phone].
David J. Meyer
Vice President and Chief Counsel for Regulatory and GovernmentalAffairs
Enclosures
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that ! have served Avista Corporation dba Avista Utilities'Advice
filing ADV 17-03-G (Tariff IPUC No. 27 Natura! Gas Service) by mailing a copy thereof,
postage prepaid to the following:
Diane Hanian, Secretary
ldaho Public Utilities Commission
472 W . Washington Street
Boise, lD 83720-5983
Edward A. Finklea
Northwest lndustrial Gas Users
545 Grandview Drive
Ashland, OR 97520
Chad Stokes
Cable Huston Benedict Haagensen &
Lloyd, LLP
1001 SW Sth, Suite 2000
Portland, OR 97204-1 1 36
Curt Hibbard
St. Joseph Regional Medical Center
PO Box 816
Lewiston, lD 83501
Spokane, Washington this 30th day of August 2017
Patrick Ehrbar
Senior Manager, State & Federal Regulation
idaho Public Utilities Commission
Otfice of the SecretaryRECEIVED
AUG 3 12017
BEFORE THE IDAHO PUBLIC UTILITIES COMMISURN IO,I,,O
IN THE MATTER OF THE APPLICATION OF )
AVISTA UTILITIES FOR AN ORDER APPROVING ) CASE: AVU-G-17-0_+
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 1,2017. If approved as filed, the Company's annual revenue will decrease by approximately
$1.7 million or about 2.7%. In support of this Application, Applicant states as follows:
I.
The name of the Applicant is AVISTA CORPORATION, doing business as AVISTA UTILITIES
(hereinafter Avista, Applicant or Company), a Washington corporation, whose principal business office
is 141 I East Mission Avenue, Spokane, Washington, and is qualified to do business in the state of Idaho.
Applicant maintains district offices in Moscow, Lewiston, Coeur d'Alene, and Kellogg, Idaho.
Communications in reference to this Application should be addressed to:
Patrick D. Ehrbar
Senior Manager, Rates and Tariffs
Avista Utilities
1411 E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
P at.ehrb ar @avi stacorp. c o m
II.
Attorney for the Applicant and his address is as follows:
David J. Meyer
Vice President and Chief Counsel for Regulatory
And Governmental Affairs
Avista Utilities
1411 E. Mission Avenue
Spokane, WA 99220-3727
Phone: [phone]
Fax: [phone]
D avi d. mey er @av istacolp. com
Case No. AVU-G-17-0_ (Advice No. l7-03-G)Page I of6
m
The Applicant is a public utility engaged in the distribution of natural gas in certain portions ofNorthern
Idaho, Eastern and Central Washington, and Southwestem and Northeastern Oregon, ffid further
engaged in the generation, transmission, and distribution of electricity in Northern Idaho and Eastern
Washington.
IV
Twenty-Fourth Revision Sheet 150, which Applicant requests the Commission approve, is filed herewith
as Exhibit "A". Additionally, Nineteenth 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-Third
Revision Sheet 150 and Eighteenth Revision Tariff Sheet 155 with the changes underlined and a copy
of Twenty-Third Revision Sheet 150 and Eighteenth 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 Idaho, a Notice in the form attached
hereto as Exhibit "B" and by means of a press release distributed to various informational agencies, a
draft copy attached hereto in Exhibit "E". In addition, Exhibit "E" to this Application also contains the
form of customer notice that the Company will send to its customers in its monthly bills 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), TransCanada - Alberta, TransCanada - BC and Spectra Energy
Pipeline systems, and defers the effect of timing differences due to implementation of rate changes and
differences between Applicant's actual weighted average cost of gas ("WACOG") purchased and the
WACOG embedded in rates. Applicant also defers various pipeline refunds or charges and
miscellaneous revenue received from natural gas related transactions including pipeline capacity
releases.
vu.
This filing reflects the Company's proposed annual PGA to: 1) pass through changes in the estimated
cost of natural gas for the November 2017 tluough October 2018 twelve-month period (Schedule 150),
Case No. AVU-G-17-0_ (Advice No. 17-03-G)Page2 of6
and 2) revise the amortization rate(s) to refund or collect the balance of deferred gas costs (Schedule
155). Below is a table summaizingthe proposed changes reflected in this filing.l
Service
Sch.
No.
101
Commodity
Change
per therm
Demand
Change
per therm
Total
Sch.150
Change
Amortization
Change
per therm
Total Rate
Change
per therm
Overall
Percent
Change
-2.50General
General 111 s (0.02167) $ (0.0083r) $ (0.029e8) s 0.00e82 $ (0.02016) -3.80i"
Commodity Costs
As shown in the table above, the estimated WACOG change is a decrease of 2.2 cents per therm. The
proposed WACOG, including the revenue conversion factor, is 21.9 cents per therm compared to the
present WACOG of 24.I cents 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 of nature 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 Staffsemi-
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 2016-2017
for the forthcoming PGA year (twelve months). Approximately 32%o of estimated annual load
requirements for the PGA year (November 2017 through October 2018) will be hedged at a fixed-price
derived from the Company's Plan. These volumes are comprised of: 1) volumes hedged for a term of
one year or less, and2) volumes from prior multi-year hedges. Through July, the hedge volumes for the
PGA year have been executed at a weighted average price of 92.62 per dekatherm ($0.26 per therm).
Ultimately, approximately 46Yo of the estimated load requirements for the PGA year will be hedged with
fixed priced natural gas purchases. These additional hedges will be executed throughout the PGA year
according to the guidelines within the Company's Plan.
The Company used a 30-day historical average of forward prices and supply basins (ending July 31,
2017) 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 68% of estimated annual load requirements
I The overall percentage change for all schedules is a decrease of 2,7%. Customers on Schedules I 12 and 132 receive either
a one-time rebate or surcharge rather than participate in the Schedule 155 amortization. The amount rebated to customers on
these schedules totaled $81,394 for an overall proposed revenue decrease of$1,737,062. The overall present billed revenue
excluding customers on l12 and 132 is $61,257,000 making the percentage decrease 2.7% (-$1,655,671 / 61,257,000: -
2.7%).
Case No. AVU-G-17-0_ (Advice No. l7-03-G) page 3 of 6
$ (0.02167) $ (0.00831) $ (0.02ee8) $ 0.00e82 $ (0.02016)
x.
for the coming year. The annual weighted average price for these volumes is $2. 14 per dekatherm ($0.21
per therm).
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 decrease
for residential customers by approximately $0.00831 per therm. This reduction is primarily due to new
transportation rates for Williams Northwest Pipeline effective both on January 1,2018 and October 1,
2otg.2
xI.
Schedule 155 / Amortization Rate Chanee
As shown in the table above, the proposed amortization rate change for Schedule 101 and Schedule I I I
is a decrease of $0.00982 per therm. The current rate applicable to Schedule 101 and Schedule 111 is
$0.09844 per therm in the rebate direction; the proposed rate is $0.08862 per therm also in the rebate
direction. The Company was able to replace most of the present rebate due, in part, to a combination of
lower actual natural gas prices versus the embedded WACOG, as well as through optimization efforts
(both storage as well as fixed transportation contract)
XII.
If approved as filed, the Company's annual revenue will deoease by approximately $1.7 million or
about 2.7Yo effective November 1,2017. Residential or small commercial customers using an average
of 61 thermspermonthwould seeadecreaseof $l.23permonth,orapproximately2.4Yo. Thepresent
bill for 6l therms is $51.10 while the proposed bill is $49.87.
XIII.
Exhibit "C" attached hereto contains support workpapers for the rates proposed by Applicant contained
in Exhibit "A".
XIV
Avista requests that the rates proposed in this filing be approved to become effective on November 1,
2017, and requests that the matter be processed under the Commission's Modified Procedure rules
through the use of wriuen comments. Avista stands ready for immediate consideration on its
Application.
2 The Williams Northwest Pipeline Settlement agreement is pending approval before the Federal Energy Regulatory
Commission (FERC).
Case No. AVU-G-17-0_ (Advice No. 17-03-G) Page 4 of 6
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 1,2017.
Dated at Spokane, Washington, this 30th day of August 2017.
AVISTA UTILITIES
BY
. Meyer
Vice President and Chief Counsel for
Regulatory and Governmental Affairs
Case No. AVU-G-I7-0_ (Advice No. l7-03-G)Page 5 of6
f7t
VERIFICATION
STATE OF WASHINGTON
County ofSpokane
David J. Meyer, being first duly sworn on oath, deposes and says: That he is the Vice President
and Chief Counsel for Regulatory and Govemmental Affairs of Avista Utilities and makes this
verification for and on behalf of Avista Corporation, being thereto duly authoized;
That he has read the foregoing filing, knows the contents thereof, and believes the same to be true.
SIGNED AND SWORN to before me this 30ft day of August 2017, by David J. Meyer
)
)
)
=S .3 gotAnr I'i ==
=.>re=='- ': Pgg;1c ,' SW
NOTAR C in and for the State of
Washington, residing at Spokane.
Commission Expires:Z)'20
Case No. AVU-G-17-0_ (Advice No. l7-03-G)Page 6 of6
ldaho Public Utilities Commission
Otfice ol the SecretaryRECEIVED
AUG 3 I 2017
Boise, ldaho
AVISTA UTILITIES
Case No. AVU-G-17-0 4
EXHIBIT "A"
Proposed Tariff Sheets
August 30,2017
l.P.U.C. No.27
Twenty-Fourth Revision Sheet 150
Replacing
Third Revision Sheet 150 150
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
naturalgas, to become effective as noted below.
RATE (a) The retail rates of firm gas Schedules 101 , 1 1 1 and 112 are to be increased
by 32.449$ per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
21.8910, per therm.
(c)The rate for transportation under Schedule 146 is to be decreased by
0.0000 per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total
Schedules 101 10.5580 21.8910, 32.4490,
Schedules 111 and 112 10.558d 21.8910, 32.4490,
Schedules 131 and 132 0.0000 21.8910, 21.8910,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.4970, 21.765Q, 32.2620,
Schedules 111 and 112 10.497Q, 21.765Q, 32.2620
Schedules 131 and 132 0.0000 21.7650, 21.7650,
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.
Effective November1,2017lssued August 30,2017
Avista UtilitiesWX.l7/^**{elly O. Norwood -Vice-President, State & Federal Regulation
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
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 WAO per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased byWO pertherm.
(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 l0l O
Schedules lll and l'12 O,
Schedules 131 and 132 0.0000 24.0580, 24.0580,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules l0l d
Schedules lll and 112 d
Schedules 131 and 132 0.0000 23Se5d------+3$35d
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 January 3,2017 Effective February3,2017
Twenty-Third Revision Sheet 150
l.P.U.C. No.27
Replacing
Revision Sheet 150 150
lssued by Avista Utilities
W Xrll, /^ *telly O. Nonrood - Vice-President, State & Federal Regulation
Twenty-Fourth Revision Sheet 150
Replacing
LP.U.C. No.27 T Revision Sheet 150 150
Avista Utilities
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 32.aa9f, per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
21.8910, 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 10't 10.558d, 21.891d, 32.4490,
Schedules 111 and 112 10.558d, 21.891d, 32.4490,
Schedules 131 and 132 0.0000 21.8916 21.8910,
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.4976, 21.7656, 32.2620,
Schedules 111 and 112 10.4976, 21.765d, 32.2620,
Schedules 131 and 132 0.0006 21.765A 21.765i,
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 30,2017 Effective November1,2017
lss Bv f fettV O. Nonivood - Vice-President, State & Federal Regulation
ruda'so"
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 8.8620 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.
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
Effective November1,2017lssued August 30,2017
Nineteenth Revision Sheet 155
l.P.U.C. No.27
Canceling
Revision Sheet 155 155
lssued by
By . t -Kelly Norwood, Vice President, State & Federal Regulation
ruah'r"J
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by W4, per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by1-W$, 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 't50 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued August 26,2016 Effective November1,2016
LP.U.C. No.27
Eighteenth Revision Sheet 155
Canceling
Seventeenth Revision Sheet 155 155
by
By 7 .Kelly Norwood, Vice President, State & Federal Regulation
ru/x.r'"J
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
decreased by 8.862d pertherm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 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
158.
lssued August 30,2017 Effective November1,2017
Nineteenth Revision Sheet 155
Canceling
hteenth Revision Sheet 155 155l.P.U.C. No.27
lssued by
By
Avista r -Kelly Norwood, Vice President, State & Federal Regulation
ru1las'-l
ldaho Public Utilities Commission
Office of the SecretaryRECEIVED
AUG 3 I 2017
Boise, ldaho
AVISTA UTILITIES
Case No. AVU-G-L7-09
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
August 30,2017
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 ldaho Public Utilities Commission
(IPUC) in Boise, Idaho.
Twenty-Fourth Revision Sheet 150 canceling Twenty-Third Revision Sheet 150
Nineteenth Revision Sheet 155 canceling Eighteenth Revision Sheet 155
Eighteenth Revision Sheet 155 updates the amortization rate used to refund or recover previous gas cost
differences and Twentieth Revision Sheet 150 updates the forward-looking cost of natural gas purchased for
customer usage.
These tariffs request an annual revenue decrease of approximately $1.6 million, or abolt 2.7%o. This filing
requests an effective date of November 7 , 2077 .
PGAs are filed each year to balance the actual cost of wholesale natural gas purchased by Avista to serve
customers with the amount included in rates. This includes the natural gas commodity cost as well as the cost to
transport natural gas on interstate pipelines to Avista's local distribution system. If the request is approved,
Avista residential customers using an average of 6l therms a month could expect their bill to decrease by 1.23, or
2.41 percent for a revised monthly bill of $49.87 beginning Nov. 1, 2017. Avista's natural gas revenues would
decrease by $1.6 million, or approximately 2.7 percent. The requested natural gas rate change by customer
segment is as follows:
General Service - Firm - Schedule 101 - Residential & Small Commercial
Large General Service - Firm - Schedules - Commercial lll & 112
High Annual Load Factor Large - Interruptible Service Schedules 132
-2.5%
-3.8%
-0.0%
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 homepage (www.puc.idaho.gov). Customers may file with the Commission written comments
related to the Company's filing. Customers may also subscribe to the Commission's RSS feed
(http://www.puc.idaho.gov/rssfeeds/rss.htm) to receive periodic updates via e-mail about the case. Copies of rate
filing are also available on our website, www.avistautilities.com/rates.
If you would like to submit comments on the proposed rate decrease, you can do so by going to the Commission
website or mailing comments to:
Idaho Public Utilities Commission
P. O. Box 83720
Boise, lD 83720-0074
Copies of the proposed tariff changes are also available for inspection in the Company's offices, its website
(www.avistautilities.com/rates), by calling [phone] or by writing:
Avista Utilities
Attention: Senior Manager, Rates & Tariffs
P.O.Box3727
Spokane, W A. 99220-37 27
August 30,2017
ldaho Public Utilities Commissionon,.*..ori.[.,?.fB*,
AUG 3 I 2017
Boise, ldaho
AVISTA UTILITIES
Case No. AVU-G-17-0 4
EXHIBIT "C"
Workpapers
August 30,2017
Title Description Page Number
TARRIF CHANGE COMPARISONS
Revenue Chanse Summarv' !A1 Change in Revenue as a result of filine 2
Rate Change Summarv'!A1 Change in rate, bv schedule, Schedule 150 and 155 3
PGA COMPONENT CATCUTATIONS
lnput!A1 Demand Volumes and Customers lnputs 4
lnput!A25 Commodity lnputs 5
Commoditv!A1 Commodity WACOG Calculation 6
lnput - Demand Contracts'!A1 Demand WACOG Calculation 7
Amortization !A1 Amortization WACOG Calcu lation 8
OTHER
Conversion Factor'!A1 Revenue Conversion Factor 9
GRI Fundine GRI Funding 10
Lost and Unaccounted for Gas Lost and Unaccounted for Gas TL
Tab: lndex Page 1 of 11
schedule
Schedule 150 PGA
Rate Schedule 101
Rate Schedule 111
Rate Schedule 112
Rate Schedule 131
Rate schedule 132
58,396,777 5
s
s
5
s
(0.02998)
(0.02se8)
(0.02998)
(0.02157)
lo.02767l
(1,7s0,s36)
l'717,584123,734,006
o
o
0
a2,734,774 12,462,7201
Schedule 155 Amortization
Rate Schedule 101
Rate Schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
Customer 1
Customer 2
Customer 3
Customer 4
54,396,777 573,375
233,O7423,738,006
0
0
o
180,s81)
(807)
a2,734,778
s (3)jJg:!-
Total Change 150 & 155
Rate Schedule 101
Rate Schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
Customer 1
Customer 2
Customer 3
Customer 4
Customer 5
54396,777
23,734,006
0
(0.02016)
{0.02015}
(0.02es8)
0.08055
(0.02157)
(1,777,7671
(478,s10)
(80,s81)
(807)
(3)
Total Change 82,134,778
Rate Schedule 146 & Special ContEcts 0
Total
s5 i'1,737,062r.
5
s 1t,737,0621
repeseC.-&le!
-e@!Ci!sC-
Revenue
47,993,000
12,775,OOO
'/6 chanse
Schedule 101
Schedule 111
Schedule 112
Schedule 131
Schedule 132
Schedule 146
Schedule 148
7,717,7671 s
s
s
s
s
s
-2.5%
-3.A%
o.eA
0.ea
o.o%
O.e/6
o.o%
Rate
Rate
(478,s10)
0
0
0 0
385,000
Tota I
Commodity
Demand
Amortization
77,443,532
8,621,960
17,211,8381
290/6
L4%
-7ZoA
Tab: Revenue Change Summary Page: 2 of 11
Therms
Rate
change
Revenue
lncr (Decr)
sI
s
s
s
0.00s82 s
0.00982 s-s
0.10222 s-s
s
s
s
s
5
s
s
Avista Utilities
State of ldaho
Summary of Changes
L
2
3
4
5
6
7
8
9
10
11
tz
13
L4
15
16
L7
18
19
20
Proposed
Rate Schedule 101
Rate schedule 111
Rate Schedule 112
Rate Schedule 131 (no customers)
Rate Schedule 132 (no customers)
Present
Change
Rate Schedule 101
Rate schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
(no customers)
(no customers)
Rate Schedule 101
Rate Schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
(no customers)
(no customers)
Total Gas Cost
Rate
50.2s9s7
s0.2s9s7
50.3s25s
s0.14270
50.2393s
50.32262
50.32262
50.32262
s0.2175s
s0.2176s
(50.08811)
(So.o88u)
So.ooooo
So.ooooo
So.ooooo
s0.234s1
S0.234s1
50.32262
s0.2175s
s0.2176s
50.00497
s0.00497
50.00000
s0.0966s
50.00000
(s0.03003)
(5o.03oo3)
(50.03003)
(50.02170)
(s0.02170)
(50.02s05)
(50.02s06)
(5o.o3oo3)
50.0749s
(So.o2uo)
Rate Sch 150
(Deferral)
s0.3s26s
s0.3s25s
s0.3s26s
50.2393s
s0.2393s
Rate Sch 155
(Amortization)
(so.os308)
(So.oe308)
s0.00000
(s0.0966s)
Total Gas Cost
Rate
s0.2s603
s0.2s503
S0.35447
s0.13835
s0.240s8
GRF:
S0.32449
s0.32449
S0.32449
s0.21891
s0.21891
s0.23s87
s0.23s87
s0.32449
s0.21891
s0.21891
1.005812
(50.08852)
(50.08862)
s0.00000
So.ooooo
s0.00000
So.oo982
50.00982
s0.00000
50.10222
s0.00000
(s0.02ee8)
(So.o2ss8)
(So.o2ee8)
(S0.02157)
(S0.02157)
(So.o2o15)
(So.o2o16)
(So.o2ee8)
s0.080ss
(S0.02157)
Rate Sch 150
(Deferral)
s0.3s447
s0.3s447
s0.35447
50.240s8
s0.240s8
Rate Sch 155
(Amortization)
(S0.09844)
(So.oe844)
s0.00000
(S0.10222)
Tab: Rate Change Summary Page 3 of 11
Summaru of Chanes Without Revenue Sensitive Costs With Revenue Sensitive Costs
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lc c c
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55ePP*T=-PPs9ii$j"igiIau*"8
hm.nd ccr ekuhion (Fr Therm)
ttn. No, Dscdlton E tmf,d Oem.nd ErreEe All4ator Per@ntr. ld.hoAllocdaon
ID
1
2
3
5
5
7
8
9
t0
11
t2
13
14
t5
16
77
18
&
2l
22B
21
25
Nonhwd PiFlhe Grpo.nbn (NwP)
TCR - GaTrzEmbrio. Nonhwd
Idltldh*i.@ffincG
T,.NGhd. - aE {NryA SFtem)
Tr.NOn.d. - BC{Fdhllb PIF tine Ltd.l
spdr. - W6t@.n Ener0 lnc
16143@ lOSFl.mAldd
s 4562,s42
s &,867
ss,ru
t 1@,e
9 S'gs
5 {1.a21
trffi
s afas
,rfl,ru
O@,@1 lOSFt.mAlldd
$.94*S4,914 loSFl.mNloc.td
IdrHodhnlnlt,dtud 9 lo$s
lod rhdPltsllE6.rF 27 #,r@
5 27.w,7@ 9 a,62t,@
-____p&il!_s 0.1@97
s ldGlt
,u860tc( aNPioftrdEEt LDC
24577 I 252,129 s 185,335 191,513 1E5,335 s 191,513 191.513 s 185,335 s 252,729 s2,614,3@
luRtSDtfrt
ON AN
PiOFIT
C€MER LDC
@c
TCPLAB
TCPL IC
555,050
237,549
555,050 s
237.3a9 s
555,050 s 555,050 9
237,539 s 237,539 I 555,050 s
237,539 5
555,050 s s55,O5O 9 sss,Oso 5 555,050 S 555,050 S 5s5,050 S s55,050 S5,660,601
237,539 $ 237,539 s 237,539 5 237,539 s 237,53r s 237,539 I 237,539 S2,850,455
'C.ndhn T,.ilM*ion prked d p.r
lnput. D€matrdConhs 7 oflT
s
s
5
s
s
ootuSs
201&
252,129
7,211,514
2om
22A,272
1,@9,748
20t&3
252,729
!,271,5)9
sI
t-477,41 $1,523,171 s
2017L7 201@1 tO1&2 m1S3 201& m1S 201S 20L&7 201@ ml@
e6332 !873,t32 I
Avista utilities
ldaho Gas Operatlons
Development of Amortization Rate
Line
No.
7
2
3
4
5
6
7
8
9
10
11
72
13
t4
15
16
77
18
Sales Therms Amortization
s (0.08811)
I nterest
7.OO%
Bala nce
Rate Schedule: 101-132 s (7,211,838)
Nov-17
Dec-17
Jan-18
Feb-18
Mar-18
Apr-18
May-18
Ju n-18
Jul-18
Aug-18
Sep-18
Oct-18
10,834,008
14,063,838
13,322,04s
10,306,119
9,310,78s
5,799,852
3,406,855
2,331,3s9
2,235,537
2,264,439
2,471,777
S
S
S
S
S
s
s
s
S
s
s
954,576.89 s
1,239,154.91 s
1,173,796.05 s
908,064.91 s
820,366.77 s
511,020.90 s
300,175.66 s
205,474.37 5
196,971.59 s
199,518.17 s
217,786.00 s
|s,672.721
|l4,702.7s!
(3,701.27|
(2,836.91)
(2,119.10)
(1,565.12)
11,229.42l-
(1,019.79)
(8s2.971,
(688.48)
(s1s.18)
s (6,262,873.39)
5 $,028,477.231
s (3,8s8,326.4s)
s (2,9s3,0s8.4s)
5 (2,134,8s0.78)
s (1,62s,3s5.00)
s 0,326,449.761s (1,122,0ss.18)
s (92s,936.s6)
5 F27,1o6.871s (s09,836.0s)
TOTAL AMORTIZATION RATES
7 ,236,837.79 (2s,0s6.48)
1.00581
Amort. Rate without revenue sensitive costs S
Tab: Amortization Page: 8 of 11
AVISTA UTILITIES
Revenue Conversion Factor
Idaho - Natural Gas System
TWELVE MONTHS ENDED DECEMBER 31,2014
(Final Settlement - per Stipulation)
Line
No.Descriotion
Revenues
Factor
I 1.000000
2
J
Expenses:
Uncollectibles 0.003407
Commission Fees 0.002371
4
5
6
7
8
Idaho State Income Tax
Total Expenses
Net Operating Income Before FIT
Federal Income Tax@35%
REVENUE CONVERSION FACTOR
REVENUE GROSS UP:
(zeroed out
for PGA)0.000000
0.005778
0.994222
0.347978
0,64624
(ut-.0s778)1.00s812
Tab: RCF (Conversion Factor)
Page: 9 of L1
Avista Utilities
State of ldaho
Voluntary GRI Funding
Previous Pipeline Rate (PerTherm)
Current Pipeline Rate (Per Therm)
Reduction in Pipeline Funding Rate (PerTherm)
Monthly Rate (Daily Rate X 355 Days/72 Months)
NWP Demand Billing Determinants
Estimated Transportation Volumes (Therms)
GRI Funding Shortfall
ldaho Percentage
Total ldaho GRI Funding Shortfall
Northwest Pipeline
TF-1 TF-1
Reservation Volumetric
Transcanada - GTN Pipeline
TF-1 TF-1
Reservation Volumetric
Total
s0.00085 s0.00088 s0.00085 s0.00088
s0.00076 s0.0007s s0.00076 s0.0007s
So.ooolo
s0.00315
ss8,08s,000
s0.00013
0
s0.00010 so.ooo13
s0.00316
0
0
s1,754,000
30.0L%
So So So
30.57% 30.OL% 30.57%
s14,000 s3,000 s9,000 s6,000 s32,ooo
Set the GRI Funding at the 1111/99 Level.
Tab: GRI Page: 10 of 11
12 MONTHS ENDED TOTAL
LOSS & UNACCOUNTED FOR GAS
BY DELIVERY POINT - THERMS
IDAHO DELIVERY
55,220,996
66,836,328
REVENUE
54,947,t08
66,807,938
LOSS +/-
273,48
28,390
Yo OF
PURCHASE
0.50
0.04
lD SPO-GDA area
lD LEWS-CLARK area
122,057,324,.21,755,487 301,837 0.25
Bonnerc
Genesee
Kellogg
Moscow
Panehurst-Kangston
Sandpoint
Smelterville-Page
IDAHO TOTAL
2,925,260
272,750
4,714,250
7,39t,730
86l,tt0
8,365,020
5,439,646
254,800
5,055,520
7,3U,622
551,107
5,77't,858
326,964
(2,514,386)
17,950
1341,2701
57,108
310,003
2,593,162
183,216
(85.ss)
6.58
(7.24)
0.77
36.00
31.00
35.91180
147,097,9
Lost and Uaccounted For Gas 1L of 11
ldaho Public Utilities Commission
Otfice oI lhe Secretary
RECEIVED
AUG 3 I 2017
Boise, ldahoAVISTA UTILITIES
Case No. AVU-G -17 -0 4
EXHIBIT'OD"
Pipeline Tariffs
August 30,2017
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2t TI-1, TFL-1 and TIL-1
(Do11ars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate(1), (3)
Minimum Maxi-mum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-lf ide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
.00000
.00000
.00000
.41000
.36263
.34234
Volumetric (2)
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
.00813
.00813
.00813
.03000
.00813
.00813
(Small Customer) (6). 00813 .'72155
Scheduled Overrun (2)00813 .44000
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual Overrun
.00000
.00813
.00813
.00813
.41000
.03000
.44000
.44000
Rate Schedule TI-l- (2)
Vol-umetri c (1 ).00813 .44000
Rate Schedule TFL-1 (4) (5)
Reservation
Volumetric (2)
Schedu]ed Overrun (2)
Rate Schedule TIL-1 (2)
Vol-umetric
2017 Attachment D Pipeline Tariffs Page 1 of 96
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, IF-z, TI-1, TFL-1 and TIL-1
(Do11ars per Dth)
Entitlement Unauthorized Overrun and Underrun (B)
( Continued)
Rate
General System Unauthorized Daily Overrun (e)
General System Unauthorized Daily Underrun 10.00000
General System Unauthorized Underrun Imbafances
not eliminated after 72 hours 10.00000
Customer-Specific Entltlement Penalty 10.00000
Footnote s
(1) Rate excfudes surcharges approved by the Commission.
(21 Annual Charge Adjustment (*ACA") surcharge may be applicable. Section
16 of the Genera] Terms and Conditions describes the basis and
applicability of the ACA surcharge.
2017 Attachment D Pipeline Tariffs Page 2 of 96
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Year
2073
2014
2075
2076
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules Tf-1, TF-2t TI-1, TEL-1 and TIL-1 (Continued)
Footnotes (Continued)
(3) To the extent Transporter dlscounts the Maximum Base Tariff Rate, such
dlscounts wiIl be applied on a non-discriminatory 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.
1-4 .
An incremental facilities charge or other payment method provi-ded for
in Section 27 or 29 of the Genera1 Terms and Conditions, is payable 1n
addition to all other rates and charges if such a charge is j-ncluded in
Exhlbit C to a Shipper's Transportation Service Agreement.
In addition to the rates set forth on Sheet No. 5, Puget Sound Energy,
Inc.'s Transportation Servlce Agreement No. 140053 is subject to an
annual incremental facillty charge pursuant to Section 21 of the
Generaf Terms and Conditions for the South Seattle Delj-very Lateral
Expansion Project. The effective annual- incremenLal facility charge is
$3,47'7,062 and i-s bil1ed in equal monthly one-twelfth j-ncrements. The
daily incremental facility charge is $0.L4651 per Dth.
In addition to the reservatj-on rates shown on Sheet No. 5, Shlppers who
contract for Cofumbia Gorge Expansi-on Project capacity are subject to a
facility reservation surcharge pursuant to Section 3.4 of Rate Schedule
TE-1. The facility charge used in deriving the Columbia Gorge Expansion
Project facility reservati-on surcharge has a minimum rate of $0 and a
maxj-mum rate durlng the indicated months or calendar years as foffows:
(Do1l-ars per Dth)
Tenth Revised Sheet No. 5-B
Superseding
Ninth Revised Sheet No. 5-B
Rate
$0.0s409
$0.0s273
$0.05137
$0.0s023
Page 3 of 96
Rate
$0.09549
$0.092ss
$0.08661
$0.08044
Year
2011
2078
2079
2020
Rate
$0.07471
$0.06876
$0 .06282
$0.0s671
Year
2027
2022
2023
2024
.Tanuary 1, 2025 March 31, 2025 90.02442
2017 Attachment D Pipeline Tariffs
STATEMENT OE RATES (Continued)
Effective Rates Appllcable to
Rate Schedul-es TE-1, TF-2t TI-1, TFL-1- and TIL-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(4) AII 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.
Por Rate Schedule TF-1, the 15-Year and 25-Year Evergreen Expansion
reservation and vofumetric rates apply to Shippers receiving service
under Rate Schedule TF-1 Evergreen Expansion service agreements. The
System-Wide reservation and volumetric rates apply to Shippers
receiving service under all other Rate Schedule TF-1 service
agreements.
For Rate Schedule TF-1f the 15-Year and 25-Year Evergreen Expansion
maximum base tariff reservation rates are comprised of $0.35843 and
$0.33814 for transmission costs and $0.00420 and $0.00420 for storage
costs, respectj-vely. The System-Wide maximum base tariff reservation
rates for Rate Schedu]e TF-1 and the maximum base tarlff reservation
rates for Rate Schedule TF-2 are comprised of $0.40580 for transmission
costs and $0.00420 for storage costs.
For 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 comprlsed of
$0.00775 for transmission costs and $0.00038 for storage costs. The
maximum base tariff volumetric rates for afl- other services under Rate
Schedufe TF-1 (Large Customer) and for services under Rate Schedul-e TF-
2 are comprised of $0.02962 for transmission costs and $0.00038 for
storage costs.
2017 Attachment D Pipeline Tariffs Page 4 of 96
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, AF-2t TI-1, TFL-1 and TIL-1 (Continued)
(Do11ars per Dth)
Footnotes (Continued)
(5) Rates for Rate Schedufes TF-1, TF-2 and TFL-1 are also appllcable to
capacity refease service except for short-term capacity release
transactj-ons for a term of one year or l-ess that take effect on or
before one year from the date on whlch Transporter is notified of the
release, which are not subject to the stated Maxi-mum Base Tariff Rate.
(Sectlon 22 of the General Terms and Condj-tions describes how blds for
capacity release will be evaluated. ) The reservation rate is the
comparable vofumetric bld reservation charge applicable to Replacement
Shippers bidding for capacity released on a one-part vofumetric bj-d
basis.
(6)For Rate Schedule TF-1 (Small Customer), the Maximum Base Tariff Rate
is compri-sed of 50.11271 for transmlssion costs and $0.00878 for
storage costs. Transporter wil-l- not schedule gas for delivery to a
Sma1l Customer subject to this Rate Schedule TF-1 under any
transportation Service Agreement (excluding its Rate Schedule TF-2
Service Agreement at Plymouth held at the tlme of storage service
unbundfing ln RP93-5) unless such Sma11 Customer has scheduled its fuIl
Contract Demand for firm service under its Rate Schedule TF-1 (Sma11
Customer) Service Agreement (s) for that day.
(7)Rate Schedule TI-1 maximum base tariff vofumetric rate is comprised of
$0.43542 for transmission costs and $0.00458 for storage costs.
Applicable to Rate Schedules TF-1, TF-2t TI-1, TFL-1 and TIL-1 pursuant
to Section 15.5 of the General Terms and Conditions.
The Unauthorized Overrun Charge per Dth is the greater of $10 or 150
percent of the highest midpoint prlce at NW Wyo. Poo1, NW s. of Green
River, Stanfield Ore., NW Can. Bdr. (Sumas), Kern Rj-ver Opa1, or E1
Paso Bondad as reflected in the Daily Price Survey published in "Gas
n:i I rr "
2017 Attachment D Pipeline Tariffs Page 5 of 96
(B)
(e)
STATEMENT OF RATES (Continued)
Effectlve Rates Applicable to Rate Schedufes DEX-1 and PAL
(Dollars per Dth)
Type of Rate
Base
Tariff Rate (1). (3)
Minimum Maximum
Rate Schedule DEX-L (2), (4)
Deferred Exchange .00000 .44000
Rate Schedule PAL
Park and Loan 00000 .44000
Footnotes
(1) Rate excludes surcharges approved by the Commission.(2) ACA surcharge may be applicabl-e. Section 16 of the General Terms and
Conditions describes the basis and applicability of the ACA surcharge
(3)To the extent Transporter discounts the maximum currently effectivetariff rate, such discounts will be applied on a non-discriminatorybasis, subject to the policies of Order No. 49'1.
(4)Shippers receiving service under this rate schedufe are required to
furnish fuef reimbursement in-kind at the rates specifled on Sheet No.
74, except as provj-ded in Section 4 of Rate Schedule DEX-1.
2017 Attachment D Pipeline Tariffs Page 6 of 96
STATEMENT OP RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2f
(Do1lars per Dth)
Rate Schedul-e and
Type of Rate
Base
Tariff Rate (1)
Minimum Maximum
Rate Schedule SGS-2E (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000
0.00000
0 .01_562
0.04056Expansion Shipper
Capacity Demand Charge
Pre-Expansi-on Shi-pper 0.00000
0.00000
0.00057
0.00348Expansion Shipper
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000
0.00000
0.00000
0.00000
0.00000
0.07562
0.04056
0.00057
0.00348
0 .00224
Expansion Shipper
Storage Charge
Pre-Expansion Shipper
Expansion Shipper
Rate Schedule SGS-2I
Volumetric
Footnotes(1) Shippers receivlng servi-ce under these rate schedufes are required to
furnish fuef relmbursement in-kind at the rates specified on Sheet
No. 74.
2017 Attachment D Pipeline Tariffs Page 7 of 96
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I (Continued)
Eootnotes (Continued)
(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 afso appJ-1cabIe 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 is
notified of the release, which are not subject to the stated Maxi-mum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
describes how bids for capaclty release will be evaluated. ) The
Withdrawal Charge and Storage Charge are applicable to Replacement
Shippers bidding for capaci-ty released on a one-part volumetri-c bid
basis.
2017 Attachment D Pipeline Tariffs Page 8 of 96
RESERVED FOR FUTURE USE
2017 Attachment D Pipeline Tariffs Page I of 96
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedufes LS-2F and LS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
Base
Tar j-f f Rate (1)
Mlnimum Maxlmum
Rate Schedule LS-2E (3)
Demand Charge (2)0.00000
0.00000
0.02587
0.00331Capacity Demand Charge (2)
Volumetric Bid Rates
Vaporization Demand-Refated Charge (2)
Storage Capacity Charge 12)
0.00000
0.00000
0.02587
0.00331
Liquefaction
Vaporizat j-on
0.90855
0.03386
0.90855
0.03386
Rate Schedule LS-2I
Volumetric 0.00000 0.00662
Liquefaction
Vaporization
0.90855
0.03386
0.90855
0.03386
Footnotes
(1) Shippers receiving service under these rate schedules are requj-red to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
1_4 .
(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.
(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 date on which Transporter is
notifi-ed of the release, which are not subject to the stated Maxj-mum
Base Tariff Rate. (Section 22 of the Genera] Terms and Conditions
describes how blds for capacity release will be evaluated. ) The
Vaporlzation Demand-Refated Charge and Storage Capaci-ty Charge are
applicable to Replacement Shippers bj-dding for capacity released on a
one-part vofumetrj-c bid basls.
2017 Attachment D Pipeline Tariffs Page 10 of96
SIATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-3F and LD-4I
(Do11ars per Dth)
Rate Schedu]e and
Type of Rate
Base
Tariff Rate (1)
Minimum Maximum
Rate Schedule LS-3E (3)
Demand Charge (2\0.00000
0.00000
0.02587
0.00331Capacj-ty Demand Charge (2)
Vol-umetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
0.00000
0.00000
0 .02581
0.00331
Liquefaction Charge (4)
Vaporization Charge
0.90855
0.03386
0.90855
0.03386
Rate Schedule LD-4I
Volumetric Charge
Liquefaction Charge (4)
0.00000
0.90855
0.18812
0.908ss
Footnotes
(1) Shi-ppers receivlng service under these rate schedules are required to
furnish fuef reimbursement j-n-kind at the rates specified on Sheet No
74.
(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.
(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 date on which Transporter is
notified of the release, which are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the Generaf Terms and Conditlons
describes how bids for capacity release will be evaluated. ) The
Vaporization Demand-Related Charge and Storage Capacity Charge are
applicable to ReplacemenL Shippers bidding for capaclty released on a
one-part vofumetrj-c bid basis.
(4)The Liquefaction Charge will be trued-up annually pursuant to Section
74.20 of the General Terms and Conditions.
2017 Attachment D Pipeline Tariffs Page 11 of96
RESERVED FOR FUTURE USE
20'17 Attachment D Pipeline Tariffs Page 12 of 96
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Nineteenth Revised Sheet No. 14
Superseding
f,ighteenth Revised Sheet No. 14
STATEMENT OF FUEL USE REQU]REMENTS FACTORS
FOR RE]MBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained ln this Tariff, Flfth Revlsed Volume No. 1
The rates set forth on Sheet Nos. 5, 6,1, B and 8-A are exclusive of
fuel use requirements. Shipper shall 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 shall be as follows
for the applicable Rate Schedufes lncfuded ln this Tariff:
Rate Schedufes TF-1, TF-2t 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-2F, LS-3F and LS-21
Liquefaction
Vaporization
Rate Schedule LD-4I
Liquefactlon
7.28%
0.503
0.15%
0. s38
0.53%
0.53%
The fuel use factors set forth above sha11 be calculated and adjusted
as explained in Section 14 of the Generaf Terms and Conditions. Fuef
reimbursement quantiti-es to be supplied by Shi-ppers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nomlnated for receipt by Transporter from Shipper for transportation,
Jackson Prairie injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable.
Footnote
(1) fn addition to the Rate Schedule TF-1 fuel- use requirements factor, the
Evergreen Expansion Incrementaf Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific PooI receipt points under
Evergreen Expansion service agreements.
2017 Attachment D Pipeline Tariffs Page '13 of 96
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Northwest Pipeline LLC DocketNo. RPlT-
STIPULATION AND SETTLEMENT AGREEMENT
Pursuant to Rule 207(a)(5) of the Rules of Practice and Procedure of the Federal Energy
Regulatory Commission ("Commission" or "FERC"), l8 C.F.R. $ 385.207(a)(5) (2016), Northwest
Pipeline LLC ("Northwest") submits this Stipulation and Settlement Agreement ("Settlement") to
modify the transportation rates set forth in Northwest's FERC Gas Tariff, Fifth Revised Volume No. I
("Tariff'), pursuant to the terms below. Northwest and the other Settling Parties (as defined in Anicle II)
stipulate and agree to the following:
BACKGROLIND
On March 15,2012, Northwest filed a Petition for Approval of Settlement in Docket No. RPl2-
490-000 (*2012 Settlement"). The 2012 Settlement satisfied the requirement to file a general rate case
under Section 4 of the Natural Gas Act ("NGA") by July 1 , 2012, as required by Northwest's previous
general rate case settlement in Docket No. RP06-416.1 On April26,2012,the Commission approved the
2012 Settlement.2
Section 14.4 of the 2012 Settlement requires Northwest to file an NGA Section 4 general rate
case not later than July I ,2017 , for rates to become effective not later than January 1,2018, unless
Northwest has entered into a pre-filing settlement effectively satisfying the NGA Section 4 general rate
case filing requirement(*2017 Rate Filing").3 In anticipation of the 2017 Rate Filing, Northwest invited
all of its shippers to engage in discussions to determine if a pre-filing settlement might be reached.
Numerous and extensive meetings and discussions among Northwest and its shippers have been held
from September 2016 through December 2016. During the course of these meetings and discussions, the
I Northwest Pipeline Corp.,ll8 F.E.R.C. n61,272 (2007).
2 Northwest Pipeline GP,l39 F.E.R.C. nil,071 (2012).
3 Because JuJy 1,2017 is a Saturday, the effective filing deadline for the 2017 Rate Filing is June 30, 2017
2017 Attachment D Pipeline Tariffs Page 14 of96
)
)
)
parties exchanged documentation, including several offers and counteroffers. This Settlement is the
product of the documents exchanged and these extensive meetings and discussions.
Through this Settlement, the Settling Partiesa have successfully resolved their issues in a
practical and carefully constructed fashion, eliminating the need for testimony, discovery, hearing and
briefing of the matters resolved. The avoidance of litigation is a valuable outcome, benefiting the
Settling Parties, the Commission and the public interest.
Northwest does not expect this Settlement to be contested because 100 percent of the shippers
who actively participated in the settlement discussions support this Settlement. Of Northwest's long-
term firm transportation and storage capacity, 92 percent support, and 8 percent do not oppose this
Settlement.
The Settling Parties agree that if this Settlement is timely approved by the Commission, then
Northwest will have satisfied the 2017 Rate Filing requirement as to the Settling Parties. Accordingly,
the Settling Parties have requested that the Commission approve this Settlement on or before March 1,
2017 , to avoid the burden of Northwest having to prepare and file the 20 I 7 Rate Filing and for the other
Settling Parties having to respond to such filing.
ARTICLE I
INDIVISIBILITY OF TERMS
The Settling Parties have engaged in extensive settlement negotiations in an effort to resolve
among themselves issues that may have been raised inthe 2017 Rate Filing and this Settlement provides
for a reasonable negotiated resolution of those issues. This Settlement is a carefully crafted compromise
among many parties with diverse and often conflicting interests. This Settlement is an integrated
package and the Settling Parties request that it be approved in its entirety, without modification or
condition.
4 "settling Parties" is defined in Article II of the Settlement.
2017 Attachment D Pipeline Tariffs Page 15of96
ARTICLE II
SCOPE OF SETTLEMENT
This Settlement shall apply to all Settling Parties. A "Settling Party" is (a) any party identified in
Appendix A or (b) any party or shipper not identified in Appendix A that either supports, or does not
oppose this Settlement as a whole and/or any of its underlying provisions. This Settlement represents a
negotiated resolution of only the issues expressly set forth in this Settlement.
ARTICLE III
ANNUAL COST-OF-SERVICE
The rates established by this Settlement ("Settlement Rates") are determined on the basis of an
annual cost-of-service of $440 million, and consist of two phases of rates. Phase I Rates, as set forth in
Appendix B, will be effective from January 1,2018, through September 30,2018, and Phase 2 Rates, as
set forth on Appendix C, will be effective from October 1,2018, through the remaining Settlement Term
(as defined in Section I L7).
ARTICLE IV
RATE DESIGN
The Settlement Rates incorporate the following specific principles with respect to rate design:
Section 4.1
General Transmission System: The rates for all transportation Rate Schedules are based on a
straight fixed variable ("SFV") rate design.
Section 4.2
Storage: The rates for the Plymouth LNG and Jackson Prairie Rate Schedules reflect an
agreement between the Settling Parties to keep the rates the same as those established in the 2012
Settlement.
Section 4.3
Evergreen l5-Year Contract Roll-In: The rates for Rate Schedule TF-l (Large Customer), TF-l
(Zl-Year Evergreen), Rate Schedule TF-2 and the Rate Schedule TI-l to be effective January l, 2018,
through September 30, 2018, as shown on Appendix B, reflect the allocation of costs to the TF-l (15-
2017 Attachment D Pipeline Tariffs Page '16 of 96
Year Evergreen) contracts. The rates for Rate Schedule TF-l (Large Customer), TF-1 (25-Year
Evergreen), Rate Schedule TF-2, and the Rate Schedule TI-l to be effective October 1,2018, through
the remainder of the Settlement Term, as shown on Appendix Co reflect the roll-in of the TF-l (15-Year
Evergreen) contracts that will expire on September 30, 2018.
ARTICLE V
DEPREC IATION. AMORTIZATION
AND NET NEGATIVE SALVAGE RATES
Section 5.1
The depreciation, amortization and net negative salvage rates used in deriving the Settlement
Rates are shown in Appendix D. Effective January 1,2018, and continuing through the Settlement
Term, Northwest will utilize the depreciation, amortization and net negative salvage rates in Appendix D
for recording depreciation, amortization and net negative salvage expenses.
Section 5.2
Northwest will continue to use separate sub-accounts to record net negative salvage.
Section 5.3
Nothing in this Settlement shall preclude Northwest from continuing to utilize accelerated
depreciation for tax purposes nor from continuing to follow Generally Accepted Accounting Principles
and the Internal Revenue Code of 1954, as amended, and regulations promulgated thereunder
(collectively, the "Code"), which utilize tax normalization.
ARTICLE VI
U.S. FEDERAL CORPORATE INCOME TAX RATE
Section 6.1
If the current U.S. federal income tax rate of 35 percent applicable to corporations should be
reduced for any taxable period(s) between January 1,2018, and the end of the Settlement Term
("Reduced Tax Rate"), then Northwest shall record in a regulatory liability account, to be ultimately
returned to the Settling Parties other than Northwest: (a) the dollar amount shown in Appendix E for the
2017 Attachment D Pipeline Tariffs Page 17 of96
Reduced Tax Rates multiplied bV (b) the number of years and/or partial years (prorated monthly) during
the Settlement Term that the Reduced Tax Rate is in effect. Northwest shall amortize the balance of the
regulatory liability account over a period of 5 years beginning with the effective date of Northwest's
new rates in the first Post-Moratorium6 NGA Section 4 or 5 general rate case filing or pre-filing
settlement.
Section 6.2
If the current U.S. federal income tax rate of 35 percent applicable to corporations should be
increased for any taxable period(s) between January 1,2018, and the end of the Settlement Term
("Increased Tax Rate"), then Northwest shall record in a regulatory asset account, to be ultimately
recovered by Northwest: (a) the dollar amount shown in Appendix E for the Increased Tax RateT
multiplied by (b) the number of years andlor partial years (prorated monthly) during the Settlement
Term thatthe Increased Tax Rate is in effect. Northwest shall amortizethe balance of the regulatory
asset account over a period of 5 years beginning with the effective date of Northwest's new rates in the
first Post-Moratorium NCA Section 4 or 5 general rate case filing or pre-filing settlement.
Section 6.3
If the current U.S. federal income tax rate applicable to corporations of 35 percent should
decrease or increase for any taxable period during the Settlement Term, then the terms and provisions of
this Article VI shall continue in effect beyond the Settlement Term until the applicable five-year
amortization period is complete.
s Any fraction ofa percent shall be rounded to the nearest one-tenth percent and the difference between the dollar amounts
reflected in Appendix E shall be interpolated accordingly.
6 The "Moratorium" is defined in Section 12.1. The phrase "Post-Moratorium" means an action having an effective date any
time on or after October 2,2018.
7 Any fraction ofa percent shall be rounded to the nearest one-tenth percent and the difference between the dollar amounts
reflected in Appendix E shall be interpolated accordingly.
2017 Attachment D Pipeline Tariffs Page 18 of96
ARTICLE VII
POST-RETIREMENT BENEFITS OTHER THAN PENSIONS
Article VI of the 2012 Settlement addresses the ongoing treatment of Post-Retirement Benefits
Other than Pensions ("PBOP"). Section 6.7 of Article VI of the 2012 Settlement provides that, "With the
exception of Section 6.1, the terms and provisions of this Anicle VI shallcontinue in effect beyond the
Settlement Term until the Commission, in response to any party carrying the burden of persuasion,
determines to modify or change the terms and provisions relating to PBOPs as set forth herein." Section
6.1 sets forth the amount of the regulatory liability that existed at that time, which has now been updated
to be $30,586,547 as of December 31, 2016,in FERC Account No. 254.
ARTICLE VIII
SETTLEMENT RATES
The Settlement Rates shown in Appendix B shall become effective January 1,2018, and remain
in effect through September 30,2018.8 The Settlement Rates shown in Appendix C shall become
effective October 1,2018, and remain in effect through the remainder of the Settlement Term. The
Settlement Rates are computed consistent with the terms of this Settlement and are reflected as daily
rates on the pro forma tariff sheets submitted herewith in Appendix F. This Settlement becoming
effective in accordance with Article XI shall constitute the Commission authority necessary for
Northwest to place into effect final tariff sheets reflecting the Settlement Rates.
ARTICLE IX
COMMENTS OF SETTLING PARTIES
Settling Parties agree that, to the extent that any comments are filed by a Settling Party with the
Commission in response to the submission of this Settlement, such comments will not be in opposition
to any provision of this Settlement.
8 To be consistent with the "Gas Day" defined in Northwest's Tariff, the Settlement Rates will become effective at 8:00 a.m.
Mountain Standard Time.
2017 Attachment D Pipeline Tariffs Page 19of96
ARTICLE X
Parties who contest one or more provisions of this Settlement will be deemed to oppose this
Settlement and shall be known as "Contesting Parties." To the extent this Settlement is approved by the
Commission, this Settlement shall become effective as to the Settling Parties (subject to their rights
described in Article XI) notwithstanding the objections of Contesting Parties. As to any Contesting Party
excluded from the terms of this Settlement pursuant to this Article X, Northwest will file an NGA
Section 4 general rate case by no later than June 30,2017, consistent with the 2017 Rate Filing
requirement, and may submit additional NGA Section 4 general rate case filings affecting the Contesting
Panies at any time thereafter. Northwest will have the same rights as to the Contesting Parties in such
Section 4 proceeding(s) as it would have had absent this Settlement. Contesting Parties shall not have
any rights or obligations under this Settlement. Except as otherwise expressly provided in this
Settlement, any Commission order during the Settlement Term related to any NGA Section 4 or 5
general rate case filing shall only become effective as to Contesting Parties. Further, no rate, surcharge,
or allocation of costs applicable to any Settling Party shall be modified as a result of the election of any
other party to become a Contesting Party.
ARTICLE XI
EFFECTIVENESS AND TERM
Section I I .l
If the Commission issues an order approving this Settlement without modification or condition,
then: (a) the Settling Parties waive any and all rights to file requests for rehearing, clarification and/or
reconsideration of such an order and (b) this Settlement shall become effective on the date that such an
order becomes a "Final Order."e If the Commission issues an order approving this Settlement subject to
e A "Final Order" means an order by the Commission for which no request for rehearing or petition for review or certiorari is
pending and for which the statutory time period within which to seek rehearing, review or certiorari has expired.
2017 Attachment D Pipeline Tariffs Page 20 of 96
modification or condition, then this Settlement shall become effective on the date that such an order
becomes a Final Order, subject to the rights of the Settling Parties enumerated in this Article XI.
Section I 1.2
If the Commission issues an order approving this Settlement subject to modification or condition,
then within seven (7) calendar days of the date of such an order, the Settling Parties will initiate a good-
faith meet-and-confer process to: (a) determine whether the Commission-imposed modification or
condition can be accepted by all Settling Parties, or, if not, then (b) make such mutually agreeable
changes to this Settlement as are necessary so it is acceptable to all the Settling Parties. If within
fourteen (14) calendar days of the date of such an order the Settling Parties are unable to mutually agree
as provided for in (a) or (b) in the preceding sentence, then the obligation to meet and confer in good
faith shall cease and the Settling Parties may pursue their rights set forth in Sections I 1.3, I L4, I 1.5 and
I 1.6.
Section I 1.3
If the Commission issues an order approving this Settlement subject to modification or condition,
then within twenty-one (21) calendar days of the issuance of such an order and following the good faith
efforts prescribed in Section I 1.2, Northwest shall provide written notice to the Commission and all
parties in this proceeding stating whether it will withdraw this Settlement and, if it does not withdraw
this Settlement, whether it will seek rehearing of such order. Failure to provide such notice shall be
deemed Northwest's election not to withdraw this Settlement, but shall not prevent Northwest from
seeking rehearing. If Northwest does not withdraw this Settlement, then this Settlement shall remain in
effect with the modification or condition required by the Commission, subject to the outcome of any
request for rehearing. If Northwest elects to file a request for rehearing, it must be consistent with the
terms of this Settlement and no other Settling Party shall oppose such a request for rehearing.l0 Within
l0 However, another Settling Party may challenge whether Northwest's request for rehearing is, in fact, consistent with the
terms of this Settlement.
2017 Attachment D Pipeline Tariffs Page 21 of96
seven (7) calendar days of a Final Order denying any request for rehearing that is consistent with this
Settlement, Northwest shall have the option to withdraw this Settlement by providing written notice of
withdrawal of this Settlement to the Commission and all parties in this proceeding.
Section I 1.4
If the Commission issues an order approving this Settlement subject to modification or condition,
then within twenty-one (21) calendar days of the issuance of such an order and following the good faith
efforts prescribed in Section 11.2, each Settling Party that no longer supports the settlement, other than
Northwest shall provide written notice to the Commission and all parties in this proceeding stating it will
no longer continue participating in this Settlement. Failure to provide such notice shall be deemed such
Settling Party's election to continue its participation in this Settlement, but shall not prevent such
Settling Party from seeking rehearing. If such Settling Party continues participating in this Settlement,
then such Settling Party shall be bound by this Settlement as modified or conditioned by the
Commission, subject to the outcome of any request for rehearing. If such Settling Party elects to file a
request for rehearing, it must be consistent with the terms of this Settlement and no other Settling Party
will oppose such request for rehearing.l I Within seven (7) calendar days of a Final Order denying any
request for rehearingthat is consistent with this Settlement, any Settling Party other than Northwest shall
have the option to cease participating in this Settlement by providing written notice of withdrawal from
participation in this Settlement to the Commission and all parties in this proceeding.
Section I 1.5
If a Settling Party other than Northwest provides notice in compliance with Section I I .4 that it
no longer wishes to participate in this Settlement, then such Settling Party shall cease to be a Settling
Party and shall be deemed to be a Contesting Party as of the date of such notice. Within seven (7)
calendar days of receipt of a notice that any Settling Party other than Northwest elects to become a
11 However, another Settling Party may challenge whether such Settling Party's request for rehearing is, in fact, consistent
with the terms of this Settlement.
2017 Attachment D Pipeline Tariffs Page 22 of 96
Contesting Party, Northwest shall have the option, but not the obligation, to withdraw this Settlement by
providing written notice of withdrawal of this Settlement to the Commission and all parties in this
proceeding.
Section I 1.6
If Northwest withdraws this Settlement in compliance with this Article XI or this Settlement is
otherwise rejected in its entirety in a Final Order, then all Settling Parties' rights, obligations and
commitments under this Settlement are deemed null and void, and all Settling Parties are returned to the
status quo onte.
Section I 1.7
The term of this Settlement shall begin on the effective date determined in accordance with this
Article XI and shall end the day before Northwest's new rates become effective pursuant to the first
Post-Moratorium NGA Section 4 or 5 general rate case filing or pre-filing settlement ("Settlement
Term").12
ARTICLE XII
MORA FILING REOUIREMENT
Section 12.1
This Settlement establishes a moratorium on any Settling Party proposing any NGA Section 4 or
5 changes to the levels of Northwest's general rates or other matters specifically addressed and resolved
by this Settlement that would seek to place such new rates or changes into effect as among the Settling
Parties any earlier than October 2,2078 ("Moratorium"). The Moratorium will not preclude Northwest
from making other filings at FERC that do not conflict with or change the provisions of this Settlement
such as: requests for authorization to construct and operate new facilities; requests to provide new
services not covered by this Settlement; requests for incremental, maximum recourse and/or other rates
and/or rate schedules associated with such new facilities or new services; requests for new or modified
12 However, there are certain provisions of this Settlement that will by their express terms survive beyond the end of the
Settlement Term.
2017 Attachment D Pipeline Tariffs Page 23 of 96
terms or conditions of service; entering into discounted rate agreements; entering into negotiated rate
agreements; or other tariff changes that do not change the provisions of this Settlement, including, but
not limited to, adjustments for fuel, rate adjustments for the recovery of surcharges for items such as the
Commission's Annual Charge Adjustment and contributions to the Gas Technology Institute, or
compliance tariff changes required under this Settlement or by the Commission.
Section 12.2
Neither Northwest nor any other Settling Party shall be precluded from seeking enforcement of
the terms of this Settlement.
Section 12.3
To the extent that the Commission considers any change to the provisions of this Settlement
during the Moratorium, the standard of review for any changes to this Settlement proposed by a Settling
Party shall be the Mobile-Sierra"public interest" standard.13 The standard of review for changes
proposed by a non-Settling Party or the Commission, acting sua sponte, shall be the ordinary 'Just and
reasonable" standard. la
Section 12.4
Northwest will file an NGA Section 4 general rate case at FERC for rates to become effective
not later than January I , 2023 , unless: (a) Northwest has entered into a pre-filing settlement or (b) a
Post-Moratorium NGA Section 5 general rate case has been filed on or before January 1,2023,
regarding Northwest's rates.
13 UritrdG^PipeLinev.MobileGasServiceCorp.,350U.S.332(1956), FederalPowerCommissionv.sierraPacific
Power Co.,350 U.S. 348 (1956), and Morgan Stanley Capital Group, Inc. v. Public Utility District No. I of Snohomish
County,554 U.S. 527 (2008) (Morgan Stanley).
ta See Morgan Stanley,554 U.S. at 535.
2017 Attachment D Pipeline Tariffs Page 24 of 96
ARTICLE XIII
RESERVATIONS
Section l3.l
The various provisions of this Settlement are not severable. If this Settlement does not become
effective in accordance with Article XI, then it shall be privileged, and all discussions held and materials
provided by any party in reaching this Settlement shall be treated as if it were subject to Rule 602 of the
Commission's Rules of Practice and Procedure, l8 C.F.R $385.602 (2016), regardless of whether Rule
602 applies. The provisions of this Settlement relate only to the specific matters resolved by this
Settlement and no Settling Party waives any claim or right which it otherwise may have with respect to
any matters not expressly provided for in this Settlement.
Section 13.2
The Commission's approval of this Settlement shall constitute a finding that the Settlement is fair
and reasonable and in the public interest, but shall not constitute a determination on the merits of the
specific provisions of this Settlement. The Commission's approval of this Settlement shall not constitute
Commission precedent regarding any principle or issue. The methods or practices observed in deriving
rates and the presence or absence of methods of establishing rates as referenced in this Seulement shall
not be used to prejudice any otherwise available rights or arguments of any participant in a future
proceeding, other than to enforce the terms of this Settlement or collect rates due for the service
provided while this Settlement remains in effect, and shall not be used as evidence that a particular
method is a "long-standing practice" as that term is used in Columbia Gas Transmission Corp. v. FERC,
628F.2d 578 (D.C. Cir. 1979), or a "settled practice" as that term is used in Public Service Commission
of New Yorkv. FERC,642F.2d 1335 (D.C. Cir. 1980).
Section 13.3
No party shall be deemed the drafter of this Settlement, and this Settlement shall not be
construed against any party as the drafter.
2017 Attachment D Pipeline Tariffs Page 25 of 96
Section 13.4
This Settlement shall be interpreted in accordance with and governed by the laws of the State of
Utah, without regard to its conflicts of laws principles.
ARTICLE XIV
POTENTTAL TIMTNG ISSUES
Section 14.1
If the Settlement approval process is not completedl5 before June 30, 2017 , thenNorthwest will
file an NGA Section 4 general rate case to satisfy the 2017 Rate Filing requirement. The other Settling
Parties shall have the right to respond to such filing without limitation or restriction. If the Settlement
approval process is completed after June 30, 2017,but before January 1,2018, then Northwest will
withdraw the 2017 Rate Filing as to the other Settling Parties. If the Settlement approval process is
completed on, or after January I , 2018, then Northwest will withdraw the 2017 Rate Filing as to the
other Settling Parties and refunds and surcharges willbe addressed in accordance with Section 14.2.
Section 14.2
If the Settlement approval process is completed by January 1,2018, then no refund or surcharge
will be due any Settling Party. If the Settlement approvalprocess is completed after January 1,2018,
then any refunds and surcharges resulting from the 2017 Rate Filing will be assessed so as to place the
Settling Parties in the same position as if the Settlement approval process had been completed by
January 1,2018.
ARTICLE XV
NO RECENT RATE REVIEW
This Settlement does not constitute a recent rate review under the Commission's Policy
Stqtement on Cost Recovery Mechanismsfor Modernization of Natural Gas Facilities,l5l FERC 1T
r5 Completion of the Settlement approval process means a Final Order by the Commission from which: (a) Northwest has no
remaining right to withdraw pursuant to Sections I I .3 or I 1 .5 (if applicable) and (b) no other Settling Party has a remaining
right to cease its participation pursuant to Section I 1.4 (ifapplicable).
2017 Attachment D Pipeline Tariffs Page 26 of 96
61,047, clarification denied,152 F.E.R.C.nil,046 (2015) ("Policy Statement"). This Article XV shall
not preclude Northwest from requesting Commission approval of a cost recovery mechanism
pursuant to the Policy Statement that would take effect after the Moratorium.
DATED this 23'd day of January,2017.
Respectfully submitted
NORTHWEST PIPELINE LLC
Laren Gertsch
Director, Rates & Taritrs
Northwest Pipeline LLC
295 Chipeta Way
P.O. Box 58900
Salt Lake city, utah 84158-0900
(801) s84-7200
(801) s84-7764 (facsimile)
Laren. [e-mail]
Bruce Reemsnyder
Senior Counsel
Northwest Pipeline LLC
295 Chipeta Way
P.O. Box 58900
Salt Lake City, Utatr 84158-0900
(801) s84-6742
[phone] (facsimile)
[e-mail]
2017 Attachment D Pipeline Tariffs
t4
Page 27 of 96
Appendix A
Appendix B
Settling Parties
Summary of Daily Settlement Rates Exclusive of Surcharges Effective January 1,
2018, through September 30, 2018
Appendix C Summary of Daily Settlement Rates Exclusive of Surcharges effective October l,
201 8
Appendix D
Appendix E
Summary of Depreciation, Amortization and Net Negative Salvage Rates
Regulatory Asset or Liability Related to Change in U.S. Federal Corporate
Income Tax Rate
Appendix F Pro Forma Tariff Sheets
20't7 Attachment D Pipeline Tariffs Page 28 of 96
CERTIFICATE OF SERVICE
I hereby certifu that I have this day served the foregoing Petition for Approval of Settlement and
Stipulation and Settlement Agreement on each of Northwest Pipeline LLC's shippers and affected state
regulatory commissions.
Dated this 23'd day of January,2}l7
Bruce Reemsnyder
Senior Counsel
Northwest Pipeline LLC
295 Chipeta Way
P.O. Box 58900
Salt Lake city, utah 84158-0900
(80r) s84-6742
[phone] (facsimile)
Bruce. [e-mail]
2017 Attachment D Pipeline Tariffs
t6
Page 29 of 96
Northwest Pipeline LLC
Docket No. RP17-
Settling Parties
Appendix A
Supporting:
Avista Corporation
Cardinal FG Company
Cascade Natural Gas Corporation
Citadel Energy Marketing LLC
City of Blanding
City Of Ellensburg
City Of Enumclaw
Cross Timbers Energy Services, Inc.
Cyanco Company, LLC
EP Minerals, LLC
FortisBC Energy Inc.
Georgia-Pacific LLC
Harvey's Tahoe Management Co., Inc.
Idaho Power Company
Idahoan Foods, LLC
IGI Resources, Inc.
Intermountain Gas Company
International Paper
Kinect Energy Group
Longview Fibre Paper and Packaging, Inc
Newmont USA Ltd
Northwest Industrial Gas Users
Northwest Natural Gas Company
Northwest Pipeline LLC
Occidental Energy Marketing, Inc.
Portland General Electric Company
Premier Magnesia, LLC
Puget Sound Energy, Inc.
Questar Gas
Roseburg Forest Products
Shell Energy North America (US), L.P.
Sierra Pacific Power Company
Snohomish County PUD No. I
Southwest Gas Corporation
Town Of Rangely
United States Gypsum Company
2017 Attachment D Pipeline Tariffs Page 30 of 96
Northwest Pipeline LLC
Docket No. RP17-
Settling Parties
(continued)
Not Opposing:
Black Hills Gas Distribution,LLC
Chevron U.S.A. Inc.
C learwater Paper Corporation
Columbia Properties Tahoe, LLC dba Mont Bleu Resort Casino & Spa
Columbia Pacific Bio-Refi nery
Evraz Inc. NA
Frederickson Power LP
Marathon OilCompany
Morgan Stanley Capital Group Inc.
Nippon Dynawave Packaging Co.
North Pacific Paper Company, LLC
Pacificorp
Public Utility District No. 1 of Clark County
The Boeing Company
TransAlta Energy Marketing (US) Inc.
Weyerhaeuser NR Company
Appendix A
2017 Attachment D Pipeline Tariffs Page 31 of96
Appendix B
NORTHWEST PIPELINE LLC
DocketNo. RPl7-
Summary of Daily Settlement Rates 1/
Exclusive of Surcharges
Effective January 1,2018
Line Rate Schedule Rate
(a)(b)
1 TF-l
2 Resenation Charge - Large Customer
3 -Erergreen-15-year
4 - Erergreen -25-year
$0.39294
$0.35077
$0.32093
5
6
7
8
9
10
11
12
13
't4
15
16
17
18
't9
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
Volumetric Charge - Large Customer
- E\ergreen - 1s-Year
- Erergreen - 25-year
- Small Customer
rF-2
Resenation Charge
Volumetric Charge
Tt-1
Maximum Volumetric Charge 2l
Minimum Volumetric Charge
SGS-2F Pre-Expansion
Demand Cha€e
Capacity Demand Charge
SGS-2F Expansion
Demand Charge
Capacity Demand Charge
SGS-2I
Volumetric Charge
SGS-2F Volumetric Bid Rates Pre-Expansion
Withdrawal Charge
Storage Charge
SGS-2F Volumetric Bid Rates Expansion
Withdrawal Charge
Storage Charge
LS-2F
Demand Charge
Capacity Demand Charge
Liquehction Charge
Vaporization Charge
LS-2r 3/
Maximum Volumetric Charge
Minimum Volumetric Charge
LS-2F Volumetric Bid 3/
Vaporization Demand Related Charge
Storage Capacity Charge
DEX-1
Maximum Volumetric Charge
Minimum Volumetric Charge
PAL
Maximum Volumetric Charge
Minimum Volumetric Charge
$0.00832
$0.00832
$0.00832
$0.69427
$0.39294
$0.00832
$0.401 26
$0.00832
$0.01 562
$0.00057
$0.04056
$0.00348
$0.00224
$0.01 562
$0.00057
$0.04056
$0.00348
$0.02587
$0.00331
$0.90855
$0.03386
$0.00662
$0.00000
$0.02587
$0.00331
$0.401 26
$0.00000
$0.40126
$0.00000
46 Facilities Resenation Surcharge for the Columbia Gorge 1999 Expansion 4/$0.09855
1/ Refects resenation, demand and capacity demand charges as daily rates.
2/ Designed on a 100% load factor basis ofthe Rate Schedule TF-1 (Large Customer) rates.
3i LS-21 and LS-2F \olumetric bid service will also be assessed Rate Schedule LS-2F liquehction and \aporization charges.
4/ Rates for the years 201 8 forward are as follows (surcharge ends March 31, 2025\:
2018
2019
2020
2021
2022
2023
$0.09855
$0.091 89
$0.08667
$0.081 94
$0.07696
$0.071 992024 $0.066802017 Afiac)T1tnt Bf.&ryBSp rariffs Page 32 of 96
Appendix C
NORTHWEST PIPELINE LLC
DocketNo. RP17-
Summary of Daily Settlement Rates 1/
Exclusive of Surcharges
Effective October 1, 2018
Line Rate Schedule Rate
(a)(b)
1 TF-12 Resenation Charge - Large Customer3 -Ewrgreen -25-yeat
$0.39033
$0.32039
5 Volumetric Charge - Large Customer6 -Ewrgreen-25-year7 - Small Customer8 TF-29 Reservration Charge10 Volumetric Charge't1 Tt-112 Maximum Volumetric Charge 2/13 Minimum Volumetric Charge14 SGS-2F Prc-Expansion15 Demand Charge16 Capacity Demand Charge
17 SGS-2F Expansion18 Demand Charge'19 Capacity Demand Charge
20 sGS-2r21 Volumetric Charge22 SGS-2F Volumetric Bid Rates Pre-Expansion23 Withdrawal Charge24 Storage Charge25 SGS-2F Volumetric Bid Rates Expansion26 Withdrawal Charge27 Storage Charge28 LS.2F29 Demand Charge30 Capacity Demand Charge31 Liquehction Charge32 Vaporization Charge33 LS-2r 3/34 Maximum Volumetric Charge35 Minimum Volumetric Charge
36 LS-2F Volumetric Bid 3/37 Vaporization Demand Related Charge38 Storage Capacity Charge39 DEX.140 Maximum Volumetric Charge41 Minimum Volumetric Charge42 PAL43 Maximum Volumetric Charge44 Minimum Volumetric Charge
$0.00832
$0.00832
$0.69427
$0.39033
$0.00832
$0.3986s
$0.00832
$0.01 562
$0.00057
$0.04056
$0.00348
$0.00224
$0.01 562
$0.00057
$0.04056
$0.00348
$0.02587
$0.00331
$0.90855
$0.03386
$0.00662
$0.00000
$0.02587
$0.00331
$0.39865
$0.00000
$0.39865
$0.00000
45 Facilities Rese^ation Surcharge fcr the Columbia Gorge 1999 Expansion 4/$0.09855
1/ Reflects resenation, demand and capacity demand charges as daily rates.
2 Designed on a 100% load hctor basis of the Rate Schedule TF-'l (Large Customer) rates.
3/ LS-21 and LS-2F rclumetric bid senice will also be assessed Rate Schedule LS-2F liquehction and wporization charges.
4/ Rates fcr the years 2018 brward are as follows (surcharge ends March 31,2025):
2018
2019
2020
2021
2022
2023
2024
$0.09855
$0.09189
$0.08667
$0.08194
$0.07696
$0.07199
$0.06680
2017 Attac?%8nt 8$?83fn2. r.'inr Page 33 of 96
NORTHWEST PIPELINE LLC
DocketNo. RPl7-
Summary of Depreciation, Amortization and Net Negative Salvage Rates
Net
Skaight NegativeLine SalvageRate Rate(c) (d)
Appendix D
Line
(a)
Description
(b)
General Sptem Transmission
Eraergreen 1S-Year
Errergreen 25-Year
Other Transmission:
Albertson's
Berwick
Centralia
Columbia Gorge
Elmore
Nampa
North Seattle
Olympia
Sonth Seattle
Tumwater
Underground Storage Plant (Pre-Epansion and Expansion)
Other Storage Plant- LNG
General Plant:
Structures and lmprovements 1/
Office Fumiture
Computer Hardware
ComPuter Softrvare
Office Equipment
Transportation Equi pment
Tools, Shop, and Garage Equipment
Laboratory Equipment
Power Operated Equipment
Communications Equipment
Communications Eq ui pment -Telephone
Communications Structures
Communications SCADA
Miscellaneous Equi pment
lntangible Plant:
Organization
Franchises and Consents
Miscellaneous lntargible Plant
Total
Rate
(e)
1
2
3
4
5
6
7I
9
10
11
12
13
14
15
16
17
18
19
20
2'.1
22
23
24
25
26
27
28
29
30
31
32
33
34
35
2.500
2.95Yo
2.95Yo
6.67o/o
3.92%
5.00%
4.44%
3.33%
6.67Yo
6.67Yo
6.67%
6.67o/o
5.00%
2.23o/o
1.45Yo
LOL
6.67Yo
33.33%
20.00yo
6.67Yo
25.00o/o
6.670
10.00o/o
12.00Yo
6.67Yo
6.67Yo
4.00Yo
10.00%
10.00%
4.00o/o
4.00Yo
6.67Yo
0.30%
0.30%
0.30%
2.80%
3.250h
3.25Yo
0.30%
0.30%
0.30%
0.30%
0.30%
0.30%
0.30%
0.30%
0.30%
0.30%
0.53%
Q.15Yo
6.97o/o
4.220/o
5.30%
4.74o/o
3.63%
6.97o/o
6.97Yo
6.97o/o
6.970h
5.30%
2.760/0
1.60%
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
LOL
6.67Yo
33.33%
20.00o/o
6.67o/o
25.00%
6.67%
10.00%
12.00o/o
6.67Yo
6.67%
4.OOoh
10.00%
10.00%
4.OO%
4.00o/o
6.67%
1/ LOL means "Life of Lease"
2017 Attachment D Pipeline Tariffs Page 34 of 96
Appendix E
Northwest Pipeline LLC
Docket No. RPIT-
Regulatory Asset or Liability Related to Change in Federal lncorne Tax Rate
Line
Change From
35% Rate
(a)(b)(c)
1
2
3
4
5
6
7
8I
10
11
12
13
14
15
16
17
18
't9
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
Rate lncreases
360/o
37%
38o/o
39%
40o/o
41%
42o/o
43%
44o/o
45To
46%
47o/o
48o/o
49o/o
5lYo
51%
52%
53%
54o/o
5SYo
560/o
57%
58o/o
59o/o
60%
61o/o
62%
63%
64%
65o/o
66%
67o/o
68o/o
69%
70%
2,079,044
4,224,089
6,438,329
8,725,167
11,088,233
13,531 ,403
16,058,820
't 8,674,919
21 ,384,450
24,192,509
27j04,570
30,126,520
33,264,699
36,525,944
39,917,639
43,447,770
47j24,991
50,958,688
54,959,068
59,137,243
63,505,335
68,076,594
72,865,532
77,888,076
83,161 ,748
88,705,865
94,541 ,777
't 00,693,144
107,186,253
114,050,398
121 ,318,315
129,026,712
137,216,885
145,935,455
155,235,263
1/ Any faction of a percent shall be rounded to the nearest one-tenth percent and the
difference between the dollar amounts reflected abo\e shall be interpolated accordingly.
2017 Attachment D Pipeline Tariffs Page 35 of 96
Federal lncome
TaxRate 1/
Appendix E
Northwest Pipeline LLC
Docket No. RP17-
RegulatoryAsset or Liability Related to Change in Federal Incone Tax Rate
(continued)
Line
Change From
35% Rate
(a)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
(b)(c)
Rate Reductions
34Yo
33o/o
32o/o
31o/o
30o/o
29Yo
28o/o
27o/o
260/o
25o/o
24Yo
23o/o
22o/o
2',t%
20To
19o/o
18%
17%
160/o
,t5Yo
14To
13o/o
12o/o
1 1o/o
10o/o
9Yo
$Yo
7o/o
6Yo
5%
4%
3o/o
2To
1o/o
0o/o
(2,016,042)
(3,971,904)
(5,870,241)
(7,713,553)
(9,504,200)
(11,244,405)
(12p36,272)
(14,581 ,786)
(16,182,827)
(17 ,741,173)
(19,258,510)
(20,736,436)
(22,176,466)
(23,580,040)
(24,948,s24)
(26,283,219)
(27,585,360)
(28,8s6,12s)
(30,096,633)
(31,307,952)
(32,491,102)
(33,647,052)
(34,776,731)
(35,881,024)
(36,960,777)
(38,016,799)
(39,049,864)
(40,060,713)
(41,050,054)
(42,018,568)
(42,966,s03)
(43,895,686)
(44,805,513)
(45,696,961)
(46,570,579)
1/ Anyfaction ofa percentshall be rounded to the nearestone-tenth percentand the
difference between the dollar amounts rellected abo\e shall be interpolated accordingly.
2017 Attachment D Pipeline Tariffs Page 36 of 96
Federal lncome
Tax Rate 1/
Appendix F
NORTHWEST PIPELINE LLC
DocketNo. RPl7-
Pro Forma Tariff Sheets
2017 Attachment D Pipeline Tariffs Page 37 of 96
RATE SETTI,EMENT PRO FORMA TARIFF SHEET - EFFECTT\rE OL/OL/20L8
STATEMENT OF RATES
Effective Rates Applicabl-e to
Rat.e Schedules TF-1, TF-2, Tf-1, TFL-1 and TIL-1(Do1lars per Dth)
Rate Schedule and
Type of Rate
Rate schedule TF-1 (4) (5)
Reservati-on
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
Volumetric (2)
(Large Customer)
System-Wide
15 Year Evergreen Exp
25 Year Evergreen Exp
(Sma11 Customer) (5)
Scheduled Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily overrun
Annual Overrun
Rate Schedule TI-1 (2)
Volumetric (7)
Rate Schedule TFL-1 (4) (5)
Reservation
VolumeEric (2)
Scheduled overrun (2)
Rate Schedule TIL-1 (2)
Vo]umetric
.00000
.00000
.00000
00832
00832
00832
.3929 4
.35077
.32093
.00832
.00832
.00832
.39294
.00832
.40126
.40]-25
.00832 .69427
00832 .40]-26
.00000
.00832
.00832
.00832
00832 .40L25
2017 Attachment D Pipeline Tariffs Page 38 of 96
BASC
Tariff Rate (1) , (3 )
Minimum Maximum
RATE SETTI'EMENT PRO FORMA TARIFF SHEET - EFFECTIVE O7/OL/20L8
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, Tf -l-, TFL-l- and TIL-l- (Continued)
Footnotes (Continued)
(3)To the exLent Transporter discounts the Maximum Base Tariff Rate, such
discounts will be applied on a non-discriminatory basis, subject to thepolicies of order No. 497.
An incrementaf facilities charge or other payment method provided for
in Section 21 or 29 of the General Terms and Conditions, is payabl-e inaddition to all other rates and charges if such a charge is included inExhibit C to a Shipper's Transportation Service Agreement.
In addition 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 theceneral Terms and Conditions for the South Seattle Delivery Lateral
Expansion Project. The effective annual incremental facility charge is
93,625,910 and is b111ed in equal monthly one-twel-fth increments. The
daily incremental facility charge is $0.L5546 per Dth.
In addition to the reservation rates shown on Sheet No. 5, Shippers who
contract for Columbia corge Expansion Project capacity are subject to afacility reservati-on surcharge pursuant to Section 3.4 of Rate Schedule
TF-1. The facility charge used in deriving the Columbia corge ExpansionProject facility reservation surcharge has a minimum rate of $0 and a
maximum rate during the indicat.ed months or calendar years as follows:
(DoIlars per Dth)
Year
20]-8
2049
2020
Rate
$0.098ss
$0.09189
$0.08557
Year
2021,
2022
Rate
$0.08194
$0.07595
Year
2023
2024
Rate
$0.07r_99
$0.05580
,January 1, 2025 - March 31, 2025 $0.05552
2017 Attachment D Pipeline Tariffs Page 39 of 96
Shippers receiving service under these rate schedules are required to
furnish fuef rej-mbursement in-kind ac the rates specified on sheet No.
]-4.
RATE SETTLEIIENT PRO FORI{A TARIFF SHEET - EFFECTIVE OL/OL/20L8
STATEMENT OF RATES (Continued)
Effective Rates App1j-cab1e to
Rate Schedules TF-l-, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Do11ars per Dth)
Footnotes (Continued)
(4) A11 reservation rates are daily rates computed on the basis of 355 daysper year, except that such rates for leap years are computed on the
basis of 355 daYs.
For RaCe Schedule TF-1, the 15-Year and 25-Year Evergreen Expansion
reservation and volumetri-c rates apply to Shippers receiving service
under Rate Schedule TF-l- Evergreen Expansion service agreements. The
System-Wide reservation and volumetric rates apply to Shippers
receiving service under all other Rate Schedule TF-1 servj-ce
agreements.
For Rate Schedule TF-1, the l-5-Year and 25-Year Everg'reen Expansion
maximum base tariff reservation rates are comprised of $0.34541- and
$0.31557 for transmissj-on costs and $0.00435 and $0.00435 for storage
costs, respectively. The System-Wide maximum base tarj-ff reservatj-on
rates for Rate Schedule TF-1 and the maximum base tariff reservationrates for Rate Schedule TF-2 are comprised of $0.38858 for transmission
costs and $0.00436 for storage costs.
For Rate Schedule TF-1 (Large Customer), the maximum base tariff
volumetri-c rates applicable to Shippers receiving service under Rate
Schedule TF-1 Evergreen Expansion service agreements are comprised of
$0.00805 for transmission costs and $0.00025 for storage costs. The
maximum base tariff vol-umetric 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 $0.00025 for
storage costs.
2017 Attachment D Pipeline Tariffs Page 40 of 96
RATE SETTI.EMENT PRO FOR}TA TARIFF SHEET - EFFECTIVE OL/OL/20L8
STATEMENT OF RATES
Effective Rat.es Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1
(Do11ars per Dth)
Rate Schedule and
Type of Rate
BaseTariff Rate(1), (3)
Minimum Maximum
Rat.e Schedule TF-r- (4) (5)
Reservation(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
00000
00000
00000
.39294=#4+
.35077+42$+
.32093-423+
Volumetric (2)
(Large Customer)
system-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
.00832-4€€t3
.00832-€€€{+
.00832-€€€-1-+
.00832#e€+.00832.#
.00832-€€€{3
(Sma11 Customer) (6). 00832:-e€€++ .69427J2+55
Scheduled Overrun (2). 00832-€€€l+ .40L264e+
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual Overrun
.00000 .39294-4€+e.00832.# .00832"-Be€+
. 00832+€€{+ .40]-26444+
. 008321-e€€{.} . 401_254444+
Rate Schedule TI-1 (2)
Volumetric (7). 00832+e€,13 .40]-26-44€+g
Rate Schedule TFL-l- (4) (5)
ReservationVolumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
2017 Attachment D Pipeline Tariffs Page 41 of 96
RATE SETTLEMENT PRO FORMA TARIFF SHEET - EFFECTIVE OL/OL/20L8
STATEMENT OF RATES (Continued)
Effective Rates applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
Footnotes (Continued)
(3) To the extent Transporter discounts the Maximum Base Tariff Rate, such
discounts will be applied on a non-discriminatory basis, subject to thepolicies of Order No. 497.
Shippers receiving service under these rate schedules are required t.ofurnish fuel reimbursement in-kind at the rates specified on Sheet No
]-4.
An incremental facilities charge or other pa)ment meLhod provi-ded for
in Section 21 or 29 of the General Terms and Conditions, is payable in
addition to all other rates and charges if such a charge is included in
Exhibit C to a Shipper's Transportation Service Agreement.
In addition Co the rates set forth on Sheet No. 5, Puget Sound Energy,
Inc.'s Transportation Service Agreement No. 140053 is subject to an
annual incremental facili-ty charge pursuant to Section 21 of the
General Terms and Conditions for the South Seattle Delivery Lateral
Expansion Project. The effective annual j-ncremental facility charge is
93,625,910 and is bi11ed in equal monthly one-twelfth increments. Thedaily incremental facility charge is $0.15545 per Dth.
In addition to the reservatj-on rates shown on Sheet No. 5, Shippers who
contract for Columbia Gorge Expansion nroject 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 corge Expansion
Project facility reservation surcharge has a minimum raEe of $0 and a
maximum rate during the indicated months or calendar years as follows:
(DoIlars per Dth)
Year
2 018
Rate
$o. o98ss
Year
2023
Rate
$0.07199
Year Rate2021- $0.08194
201-9 $0.09189 2022 $0.07595 2024 $0.055802020 $0.08567
2e16 $e , g8g1 I 2e2e 9e , e5671 2e24 $e , e5923
,January 1, 2025 - March 31, 2025 $0.06552H24.4+
2017 Attachment D Pipeline Tariffs Page 42 of 96
R.ATE SETTI.EIIENT PRO FOR^}!A TARTFF SHEET - EFFECTIVE OL/OL/20L8
STATEMENT OF RATES (ConTinued)
Effective Rates Applicable to
Rate Schedules TF-L, TF-2, TI-1, TFL-1 and TIL-l- (Conti.nued)
(Do1lars per Dth)
Footnotes (Continued)
(4) A11 reservation rates are daily rates computed on the basis of 365 days
per year, except that such rates for leap years are computed on the
basis of 365 days.
For Rate Schedule TF-1, the l-s-Year and 25-Year Evergreen Expansion
reservation and volumetric rates apply to Shippers receiving service
under Rat.e Schedule TF-l- Evergreen Expansion service agreements. The
System-Wide reservation and volumetric rates apply to Shippers
receiving service under all other Rate Schedule TF-1 service
ag,reements.
For Rate Schedule TF-1, the 1s-Year and 25-Year Evergreen Expansion
maxj-mum base tarif f reservation rates are comprised of $0.34641$.-*5€4+
and $0.315578H for transmission costs and $0.00436He4*g and
$0.00435He4*+ for storage costs, respectj-ve1y. The System-Wide
maximum base tariff reservation rat.es for Rate Schedule TF-1 and the
maximum base tariff reservation rates for Rate Schedul-e TF-2 are
comprised of $0.38858S-+S5&e for transmission costs and $0.00436s.4e4e+for storage costs.
For Rate Schedule TF-1 (Large Customer), the maximum base tariff
volumetric rates applicable to Shippers receivj-ng service under Rate
Schedule TF-L Evergreen Expansion service agreements are comprised of
$O.OOB05He++5 for transmission costs and $0.00026S.4$S39 for storage
costs. The maximum base tariff volumetric rates for all other services
under Rate Schedule TF-1 (Large CusEomer) and for services under Rate
Schedule TF-2 are comprised of $0.00806e-€€96* for transmission costs
and $0.00025$'40€3€ for storage costs.
2017 Attachment D Pipeline Tariffs Page 43 of 96
RATE SETTIJEMENT PRO FORMA TARIFF SHEET - EFFECTTVE IO/07/20]-8
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, T1-l-, TFL-1 and TIL-1
(Dollars per Dth)
RaLe Schedule and
Type of Rate
BaseTariff Rate(1), (3)
Minimum Maximum
Rate Schedule TF-1
Reservation
(Large Customer)
System-Wide
(4) (s)
25 Year Evergreen Exp
.00000
.00000
.39033
.32039
Volumetric (2)
(Large Customer)
System-Wide .00832
.00832
.00832
.00832
00832
00832
69427
3986s
(Sma11 Customer) (6)
Scheduled Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily overrun
Annual Overrun
00000
00832
00832
00832
39033
00832
39865
39855
Rate Schedule TI-L (2)
Volumetric (7)00832 .3985s
Rate Schedule TFL-1 (4) (5)
Reservation
Volumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
2017 Attachment D Pipeline Tariffs Page 44 of 96
25 Year Evergreen Exp.
RATE SETTI.EMENT PRO FORMA TARIFF SHEET - EFPECTI\/E LO/OL/20L8
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, AF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Do11ars per Dt.h)
Footnotes (Continued)
(4) A11 reservation rates are daily rates computed on the basis of 355 daysper year, except that such rates for leap years are computed on thebasis of 355 days.
For Rate Schedule TF-1, the 25-Year Evergreen Expansi-on reservation and
volumetric rates apply to Shippers receiving service under Rate
Schedule TF-1 Evergreen Expansion service agreements. The System-Wide
reservation and volumetric rates apply to Shippers receiving service
under all other Rate Schedule TF-1 service agreements.
For Rate Schedule TF-l-, the 25-Year Everg'reen Expansion maximum basetariff reservation rates are comprised of $0.31503 for transmission
costs and $0.00435 for storage costs. The System-Wide maximum basetariff reservation rates for Rate Schedule TF-1 and the maxi-mum basetariff reservation rates for Rate Schedule TF-2 are comprised of
$0.38597 for transmission costs and $0.00436 for storage costs.
For Rate Schedule TF-l- (Large Customer), the maximum base tariff
volumetric rates applicable to Shippers receiving service under Rate
Schedule TF-1 Everg'reen Expansion service agreements are comprised of
$0.00805 for transmission costs and $0.00026 for storage costs. The
maximum base tariff volumetric rates for al-1 other services under Rate
Schedule TF-1 (Large Customer) and for services under Rate Schedule TF-2 are comprised of $0.00805 for transmission costs and $0.00025 for
storage costs.
2017 Attachment D Pipeline Tariffs Page 45 of 96
RATE SETTLEMENT PRO FORMA TARIFF SHEET - EFFECTIVE LO/OL/20L8
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-L, TF-2, TI-1, TFL-1 and TIL-I-
(Do11ars per Dth)
Rate Schedule and
Type of Rate
BaseTariff Rate (1) , (3 )
Minimum Maximum
Rate schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide .00000 .39033-39a9+
i[5 Year Evergreen Er<P, , 99900 ,35077
25 Year Evergreen Exp. .00000 .3203942441
Volumetric (2)
(Large Customer)SysEem-Wide .00832 .00832
15 Year Evergreen E'<p: :90832 ;00832
25 Year Evergreen Exp. .00832 .00832
(Sma11 Customer) (5).00832 .69427
Scheduled Overrun (2).00832 .3985s.#r#
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual overrun
.00000
.00832
.00832
.00832
.39033-9294
.00832.398554,H.6
.39855:44416
Rate Schedule TI-l- (2)
Volumetric (7).00832 .39855-{#l+.6
Ratse Schedule TFL-1 (4) (5)
Reservation
Volumet.ric Q)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
2017 Aftachment D Pipeline Tariffs Page 46 of 96
RATE SETTI.EMENT PROFORMA TARIPF SHEET - EFFECTIVE LO/OL/20L8
STATEMENT OF RATES (ConLinued)
Effective Rates Applicable to
Rate schedules TF-1, lF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Do1lars per Dth)
Footnotes (Continued)
(4) A11 reservation rates are daily rates computed on the basis of 365 daysper year, except thaE such rates for leap years are computed on the
basis of 355 days.
For Rate Schedule TF-l-, the +H-ea+--a+d-25-Year Evergreen Expansion
reservation and volumetrj-c rates apply to Shippers receiving service
under Rate Schedule TF-1 Evergreen Expansion service agreements. The
System-Wide reservation and volumetric rates apply to Shippersreceiving servj-ce under all other Rate Schedule TF-1 service
agreements.
For Rate Schedu]e TF-1, the +H-eaFaaC-25-Year Evergreen Expansion
maximum base tariff reservatj-on rates are comprised of $€-'*46,I*---aEd
$0.31503HL+7 for Cransmission costs and $He43-5---aEd-$0.00435 for
storage costsT-+speesive*y. The System-Wide maximum base tariff
reservation rates for Rate Schedule TF-1 and the maximum base tariff
reservation rates for Rate Schedule TF-2 are comprised of
$0.38597H8€5"& for transmission costs and $0.00435 for storage costs.
For Rate Schedule TF-1 (Large Customer), the maximum base tariff
volumetric rates applicable to Shippers recei-ving service under Rate
Schedule TF-L Evergreen Expansion service agreements are comprised of
$0.00806 for transmission costs and $0.00025 for storage costs. The
maximum base tariff volumetri-c rates for all other services under Rate
Schedule TF-1 (Large Customer) and for services under Rate Schedul-e TF-
2 are comprised of $0.00806 for transmission costs and $0.00025 for
storage costs.
Page 47 of 962017 Attachment D Pipeline Tariffs
Gas Transmission Northwest Corporation
Fourth Revised Volume No. 1-A
Table of Gontents
Fourth Revised Volume No. 1-A
1 TABLE OF CONTENTS
2 PRELIMINARY STATEMENT
3 MAPS
4 STATEMENT OF RATES
4.1 FTS-1 and LFS-1 Rates
4.2 IS-1 Rates
4.3 Footnotes to Statement of Effective Rates and Charges
4.4 Reserved For Future Use
4.5 Parking and Lending Service
4.6 Negotiated Rate Agreements - FTS-1 and LFS-1
4.7 Footnotes for Negotiated Rates - FTS-1 and LFS-1
4.8 Negotiated Rate Agreements - ITS-1 and PAL
4.9 Footnotes for Negotiated Rates - ITS-1 and PAL
4.10 Non-Conforming Service Agreements
5 RATE SCHEDULES
5.1 Rate Schedule FTS-1 - Firm Transportation Service
5.2 Rate Schedule LFS-1 - Limited Firm Transportation Service
5.3 Rate Schedule ITS-1 - lnterruptible Transportation Service
2017 Attachment D Pipeline Tariffs Page 48 of 96
Gas Transmission Northwest Corporation
Fourth Revised Volume No. 1-A
5.4 Rate Schedule USS-1 - Unbundled Sales Service
5.5 Rate Schedule PAL - Parking and Lending Service
6 GENERAL TERMS AND CONDITIONS OF SERVICE
6.1 Definitions
6.2 Equality of Transportation Service
6.3 Quality of Gas
6.4 Measuring Equipment
6.5 Measurements
6.6 lnspection of Equipment and Records
6.7 Billing
6.8 Payment
6.9 Notice of Changes in Operating Conditions
6.10 Force Majeure
6.11 Warranty of Eligibility for Transportation
6.12 Possession of Gas and Responsibility
6.13 lndemnification
6.14 Arbitration
6.15 Governmental Regulations
6.16 Miscellaneous Provision
6.17 Transportation Service Agreement
6.18 Operating Provisions
6.19 Priority of Service, Scheduling, and Nominations
6.20 Curtailment
2017 Attachment D Pipeline Tariffs Page 49 of 96
Gas Transmission Northwest Gorporation
Fourth Revised Volume No. 1-A
6.21
6.22
6.23
6.24
6.25
6.26
6.27
6.28
6.29
6.30
6.31
6.32
6.33
6.34
6.35
6.36
6.37
6.38
6.39
6.40
6.41
6.42
6.43
2017 Attachment D Pipeline Tariffs
Balancing
Annual Charge Adjustment (ACA) Provision
lnformational Postings
Complaint Procedures
lnformation Concerning Transportation Service
Market Centers
Planned GTN Capacity Curtailments and lnterruptions
Capacity Release
Flexible Receipt and Delivery Points
Operational Flow Order (OFO) Procedures
Negotiated Rates
Reservation of Capacity for Expansion Projects
ROFR Upon Termination of Firm Service Agreement
Electronic Communications
Reserved for Future Use
Crediting of lT Revenues on Extensions
Discount Policy
Fuel Adjustment Mechanism
Reserved for Future Use
Sales of Excess Gas
Gas lndustry Standards
Pressure Commitments
Pressure at Point(s)of Receipt and Delivery
Page 50 of 96
Gas Transmission Northwest Corporation
Fourth Revised Volume No. 1-A
7 FORM OF SERVICE AGREEMENT
7.1 Rate Schedule FTS-1
7.2 Rate Schedule ITS-1
7.3 Rate Schedule PAL
7.4 Reserved for Future Use
7.5 Rate Schedule LFS-1
7.6 Reserved For Future Use
7.7 Master Service Agreement - Daily Firm, FTS-1
8 NON-CONFORMING AGREEMENTS
9 NON-CONFORMING AGMTS WITH NEGOTIATED RATES
2017 Attachment D Pipeline Tariffs Page 51 of96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
FERC GAS TARIFF
FOURTH REVISED VOLUME NO. I -A
OF
GAS TRANSMISSION NORTHWEST LLC
FILED WITH THE
FEDERAL ENERGY REGULATORY COMMISSION
Communications Concerning This Tariff
Should Be Addressed To:
Joan Collins
Manager, Tariffs and Compliance
Gas Transmission Northwest LLC
Mailing Address: P.O. Box2446
Houston, TX 77252-2446
Courier Address: 700 Louisiana Street, Suite 700
Houston, TX 77002-2700
Phone: [phone]
Fax: [phone]
2017 Attachment D Pipeline Tariffs Page 52 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4
STATEMENT OF RATES
v.2.0.0 Superseding v. 1.0.0
STATEMENT OF RATES
Issued: April 1l,20ll
Effective: April 4, 20ll
2017 Attachment D Pipeline Tariffs
Docket No. RPI l-1986-000
Accepted: May 4,2011
Page 53 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
DAILY
MILEAGE (a)
(Dth-MrLE)
SURCHARGES
ACA (k)
PART 4.I
4.1 - Statement of Rates
FTS-I and LFS-I Rates
v. I 5.0.0 Superseding v. I 4.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-l and LFS-l
RESERVATION
Max. Min. Max. Min.
BASE 0.000434 0.000000 0.034393 0.000000
STF (e)(e) 0.000000 (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-l (0 0.0027s9 0.000000
E-2 (h) 0.002972 0.000000
(Diamond l)
E-2 (h) 0.001166 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001282 0.000000
CARTY LATERAL
E-4 (p)
OVERRUN CHARGE C)
0.004641 0.000000 0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.00r283 0.000000 0.000000 0.000000
0.16647s 0.000000 0.000000 0.000000
(k) (k)
DAILY
NON-MTLEAGE (b)
(Dth)
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.0000r6 0.000016
FUEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%
0.00s0% 0.0000%
Issued: November 24, 2015
Effective: January l, 2016
2017 Attachment D Pipeline Tariffs
Docket No. RPI 6-235-000
Accepted: December 30, 2015
Page 54 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.2
4.2 - Statement of Rates
ITS-l Rates
v.6.0.0 Superseding v.5.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS (a)
Rate Schedule ITS-I
MILEAGE (n)
(Dth-Mile)
NON-MILEAGE (o)
(Dth)
Max. Min.
(e) 0.000000
DELIVERY (c)
(Dth-Mile)
Max. Min.
0.000016 0.000016
FUEL (d)
(Dth-Mile)
Max. Min.
0.00s0% 0.0000%BASE
Max. Min.
(e) 0.000000
EXTENSION CHARGES
MEDFORD
E-1 (Medford) (f)
0.002759 0.000000 0.004641 0.000000 0.000026 0.000026
COYOTE SPRINGS
E-3 (Coyote Springs) (i)
0.001282 0.000000 0.001283 0.000000 0.000000 0.000000
CARTY LATERAL
E-4 (Carty Lateral) (p)
0.166475 0.000000 0.000000 0.000000
SURCHARGES
ACA (k)(k) (k)
Issued: November 20, 2015
Effective: January l, 2016
2017 Aftachment D Pipeline Tariffs
Docket No. RP 1 6-209-000
Accepted: December 22, 2015
Page 55 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v. 13.0.0 Superseding v. 12.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes
(a) The mileage component shall be applied per pipeline mile to gas transported by GTN for
delivery to shipper based on the primary receipt and delivery points in Shipper's contract.
Consult GTN's system map in Section 3 for receipt and delivery point and milepost
designations.
(b) The non-mileage component is applied per Shipper's MDQ at Primary Point(s) of Delivery
on Mainline Facilities.
(c) The delivery rates are applied per pipeline mile to gas transported by GTN for delivery to
shipper based on distance of gas transported. Consult GTN's system map in Section 3 for
receipt and delivery point and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel, line loss, and other
utility purposes, plus other unaccounted-for gas used in the operation of GTN's combined
pipeline system in an amount equal to the sum of the current fuel and line loss percentage
and the fuel and line loss percentage surcharge in accordance with Section 6.38 of this
tariff, multiplied by the distance in pipeline miles transported from the receipt point to the
delivery point multiplied by the transportation quantities of gas received from Shipper
under these rate schedules. The current fuel and line loss percentage shall be adjusted each
month between the maximum rate of 0.0050% per Dth per pipeline mile and the minimum
rate of 0.0000% per Dth per mile. The fuel and line loss percentage surcharge is 0.0002%
per Dth per pipeline mile. No fuel use charges will be assessed for backhaul service.
Currently effective fuel charges may be found on GTN's Internet website under
" Informational Postings. "
(e) Seasonal recourse rates apply to short-term firm (STF) service under Rate Schedule FTS-I
(i.e., firm service that has a term of less than one year and that does not include multiple-
year seasonal service) and IT Service under Rate Schedule ITS-1. By March I of each year
GTN may designate up to four (4) months as peak months during a twelve-month period
beginning on June I of the same year through May 3l of the following year. All other
months will be considered off-peak months. Reservation rate components that apply to
STF service and per-unit-rate IT service are as follows (delivery charges and applicable
surcharges continue to apply):
4 Peak
Mos.
$0.048150
$0.000608
3 Peak
Mos.
$0.048150
$0.000608
2Peak
Mos.
s0.0481s0
$0.000608
I Peak
Mo.
$0.0481s0
$0.000608
0 Peak
Mos.
$0.034393
$0.000434
Peak NM Res.
Peak Mi. Res.
Issued: November 21, 2016
Effective: January 1,2017
2017 Attachment D Pipeline Tariffs
Docket No. RPI 7-l 88-000
Accepted: December 13, 2016
Page 56 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Off-PkNM Res.
Off-Pk Mi. Res.
PART 4.3
4.3 - Statement of Rates
Footnotes to Statement of Effective Rates and Charges
v. I 3.0.0 Superseding v. 12.0.0
$0.027515
$0.000347
$0.029807
$0.000376
$0.031642
$0.000399
$0.033142
$0.000418
$0.034393
$0.000434
Months currently designated as "Peak Months" may be found on GTN's Internet website
under "Informational Postings." By March I of each year, GTN will post the Peak Months
for the upcoming twelve-month period beginning June 1 of the same year.
(0 Applicable to firm service on GTN's Medford Extension.
(g) Reserved for Future Use
(h) E-2 (Diamond l) is a negotiated reservation charge of $0.002972 per Dth per day for first
45,000 Dth/d andE-2 (Diamond 2) is a negotiated reservation charge of $0.001 166 per Dth
per day forthe second 45,000 Dth/d. During leap years, E-2 (Diamond l) is a negotiated
reservation charge of $0.002964 per Dth per day for first 45,000 Dth/d and E-2
(Diamond 2) is a negotiated reservation charge of $0.001 163 per Dth per day for the second
45,000 Dth/d.
(i) Applicable to firm service on GTN's Coyote Springs Extension.
0) The Ovemrn Charge shall be equal to the rates and charges set forth for intemrptible service
under Rate Schedule ITS-1.
(k) In accordance with Section 6.22 of the Transportation General Terms and Conditions of this
FERC Gas Tariff, Fourth Revised Volume No. 1-A, all Transportation services that involve
the physical movement of gas shall pay an ACA unit adjustment. The currently effective
ACA unit adjustment as published on the Commission's website (www.ferc.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-I Mileage Component shall be applied per pipeline mile to gas
transported by GTN based on the distance of gas transported. Consult GTN's system map
in Section 3 for receipt and delivery point and milepost designations.
(o) The Rate Schedule ITS-I Non-Mileage Component shall be applied per Dth of gas
transported by GTN for immediate delivery to the facilities of another entity or an extension
facility.
(p) Applicable to firm service on GTN's Carty Lateral Extension.
Issued: November 21, 2016
Effective: January l, 2017
2017 Attachment D Pipeline Tariffs
Docket No. RP I 7-l 88-000
Accepted: December 13, 2016
Page 57 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: May 26,2011
Effective: June 27,2011
2017 Attachment D Pipeline Tariffs
PART 4.4
4.4 - Statement of Rates
Reserved For Future Use
v.3.0.0 Superseding v.2.0.0
RESERVED FOR FUTURE USE
Docket No. RPI l-2132-000
Accepted: June 10, 201 I
Page 58 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: November 20, 2015
Effective: January 1,2016
2017 Attachment D Pipeline Tariffs
PART 4.5
4.5 - Statement of Rates
Parking and Lending Service
v.6.0.0 Superseding v.5.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS FOR
Parking and Lending Service
($/Dth)
BASE TARIFF RATEMINIMUM MAXIMUM
0.0PAL Parking and Lending Service:
Notes
0.24354Ud
Docket No. RP I 6-209-000
Accepted: December 22, 2015
Page 59 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.6
4.6 - Statement of Rates
Negotiated Rate Agreements - FTS-I and LFS-I
v.4.0.0 Superseding v.3.1 .0
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULES FTS-1 AND LFS-I
TERM OF
CONTRACT
RATE
SCHEDULE
PRIMARY
RECEIPT
POINT
Medford
PRIMARY
DELIVERY
POINTDTH/D
20,000
RATE
t2 t3SHIPPER
Avista
Corporation /1
Powerex Corp./1
tUU0l -
10131125
FTS-I Medford Ext.
Meter
l7
l5
Docket No. RPI 6-794-000
Accepted: April 26, 2016
Page 60 of 96
04t0U16 -
t013U16
FTS-I 20,000 Kingsgate Malin
Issued: April I ,2016
Effective: April I ,2016
2017 Attachment D Pipeline Tariffs
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Effective Period
tyU0t-10/31102
tyU02-10/3U03
tU1l03-10/31104
rU1t04-10/31105
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-I and LFS-1
v.6.0.0 Superseding v.5.0.0
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
lt This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
12 Unless otherwise noted, all Shippers pay GTN's maximum Reservation Charge, Delivery
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
t5 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 Reserved
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.
/6 Reserved
17 The Reservation charge shall be equal to the rate set forth in GTN's FERC Gas Tariff
identified as FTS-I E-2 (WWP), or its successor, multiplied by the appropriate Effective
Period Percentage as shown in the following table.
Percentage
75%
80%
85%
90%
Issued: April 1,2016
Effective: April 1, 2016
2017 Attachment D Pipeline Tariffs
Docket No. RPI 6-794-000
Accepted: April 26, 2016
Page61 of96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
tUU05-r013ll06
t1lU06-1013y2s
Issued: April I ,2016
Effective: April 1,2016
2017 Attachment D Pipeline Tariffs
PART 4.7
4.7 - Statement of Rates
Footnotes for Negotiated Rates - FTS-l and LFS-l
v.6.0.0 Superseding v.5.0.0
9s%
r00%
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-l E-2
18 Reserved
19 Reserved
ll0 Reserved
lll Reserved
l12 Reserved
113 Reserved
114 Reserved
115 Reserved
l16 Reserved
l17 Reserved
118 Reserved
Docket No. RP 1 6-794-000
Accepted: April 26, 2016
Page 62 of 96
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 CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS UNDER RATE SCHEDULE ITS-1 AND PAL
SHIPPER
TERM OF
CONTRACT
PRIMARY
RECEIPT
POINT
PRIMARY
DELIVERY
POINT
RATE
SCHEDULE DTH/D
RATE
12 13
lssued: April24,2015
Effective: June I ,2015
2017 Attachment D Pipeline Tariffs
Docket No. RPI 5-905-000
Accepted: May 29,2015
Page 63 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April24,2015
Effective: June 1,2015
2017 Attachment D Pipeline Tariffs
PART 4.9
4.9 - Statement of Rates
Footnotes for Negotiated Rates - ITS-l and PAL
v.5.0.0 Superseding v.4.0.0
Docket No. RP I 5-905-000
Accepted: May 29,2015
Page 64 of 96
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
NEGOTIATED RATE AGREEMENTS LINDER RATE SCHEDULE ITS-I AND PAL
Explanatory Footnotes for Negotiated Rates under Rate Schedule ITS-l and PAL
ll This contract does not deviate in any material aspect from the Form of Service Agreement
in this Tariff.
12 Unless otherwise noted, all Shippers pay GTN's maximum Mileage and Non-Mileage
Charge, ACA, and contribute fuel in-kind in accordance with this Tariff.
13 Index Price References: Unless otherwise noted, references to "Daily Index Price" shall
mean the price survey midpoint for the specified point as published in Gas Daily for the day
of gas flow. Weekend and holiday prices will be determined using the next available Gas
Daily publication. Unless otherwise noted, the references to the "NGI FOM" for a specified
point shall mean Natural Gas Intelligence's First of Month Bid Week Survey (Supplement
to NGI's Weekly Gas Index) Spot Gas Price for the specified point.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.IO
4.10 - Statement of Rates
Non-Conforming Service Agreements
v.4.0.0 Superseding v.3.0.0
Name of Shinner
NON-CONFORMING SERVICE AGREEMENTS
PURSUANT TO $ 1s4.112(b)
Contract Rate
Schedule
Effective
Date
Termination
Date
Cascade Natural Gas Corporation
Chevron USA Inc.
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 Energy North America (US), L.P.
BP Canada Energy Marketing Corp.
Sempra Energy Trading Corp.
EnCana Marketing (USA) Inc.
Nexen Marketing U.S.A., Inc.
Shell Energy North America (US), L.P.
Sierra Pacific Power Company
City of Glendale
Iberdrola Renewables, Inc.
Petro-Canada Hydrocarbons, Inc.
Chevron U.S.A. Inc.
Salmon Resources Ltd.
Constel lation Energy Commodities
Group, [nc.
Enserco Energy Inc.
ConocoPhillips Company
UBS AG (London Branch)
152
153
154
158
163
167
168
169
170
177
178
179
180
181
182
2591
2857
2858
7828
8035
lll
112
119
144
146
4621
4721
4770
6759
7047
7068
7804
7806
7807
7812
7816
FTS-1
FTS-1
FTS-1
FTS-1
FTS-1
FTS-I
FTS.I
FTS-I
FTS-I
FTS.I
FTS-1
FTS-I
FTS-1
FTS.1
FTS-1
FTS-I
FTS-1
FTS-1
FTS-1
FTS-I
ITS-I
ITS-I
ITS-1
ITS-I
ITS-I
AIS-I
AIS-1
AIS-I
AIS-I
AIS-1
AIS-1
AIS-1
AIS-1
AIS-1
AIS-1
AIS-1
11/111993
ly111993
11t1n993
111111993
111111993
11t1n993
1yyt993
11t1n993
lU111993
tl/Ut993
rU1lt993
tUUt993
tUU1993
tUUt993
tUy1993
81111995
tUUt995
1U111995
6131200r
tUy200t
2lyt992
4lUt992
412211992
712311993
81111993
t2lUt996
UUt997
U2511997
6t17t1999
411012000
412712000
513012001
s13012001
st30t200t
513012001
513012001
1013112023
1013112023
1013U2023
1013112013
10t31t2023
1013U2023
1013U2023
1013U2023
10t31t2023
1013U2023
10t31t2023
1013U2023
10t3U2023
1013U2023
10/31/2023
10t31/202s
10t31t2025
10t311202s
1013112025
1013112025
1013U2010
3l3U20tt
4l22l20tt
9t30t2010
81112010
12131/2010
1213U2010
12t3112010
1213U2010
1213U2010
121412019
1213U2021
1213112021
1213112021
1213U2021
1213112021
AIS-1
AIS-I
AIS-I
AIS-I
81212001
1112712001
U812002
4111t2002
813112021
1113012021
U31t2022
413012023
Issued: September 25, 2015
Effective: October 26, 2015
2017 Attachment D Pipeline Tariffs
Docket No. RP I 5-l 294-000
Accepted: October 23, 2015
Page 65 of 96
8038
8176
8228
8318
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Issued: September 25,2015
Effective: October 26, 2015
2017 Attachment D Pipeline Tariffs
PART 4.10
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.
Merrill Lynch Commodities, Inc.
Apache Corporation
Tenaska Marketing Ventures
California Dept. of Water Resources
United Energy Trading, LLC
Select Natural Gas LLC
National Fuel Marketing Company LLC
Fortis Energy Marketing & Trading GP
Powerex Corp.
Louis Dreyfus Energy Services L.P.
Pacific Summit Energy LLC
Devlar Energy Marketing, LLC
Suncor Energy Marketing Inc.
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequent Enerry Management LP
Occidental Energy Marketing, Inc.
NextEra Enerry Power Marketing, LLC
Natural Gas Exchange, Inc.
Citigroup Energy Inc.
IGI Resources, Inc.
Macquarie Cook Energy, LLC
Sempra Enerry Trading Corp.
EnCana Marketing (USA) Inc.
Shell Energy North America (US), L.P.
Husky Gas Marketing Inc.
Enserco Energy Inc.
National Fuel Marketing Company LLC
United States Gypsum Company
Northwest Natural Gas Company
Chevron U.S.A. Inc.
San Diego Gas & Electric Company
Southern California Gas Company
Puget Sound Energy, Inc.
Hermiston Generating Company, L.P.
City of Glendale
Iberdrola Renewables, Inc.
Questar Enerry Trading Company
El Paso Energy Marketing Company
Sempra Enerry Trading Corp.
Constellation Energy Commodities
Group, Inc.
ConocoPhillips Company
Tractebel Energy Marketing, Inc.
UBS AG (London Branch)
8421
8559
8594
8674
8670
8880
8887
9002
8978
903s
9l l5
9149
9281
9285
9630
9774
10197
r 0308
I 0336
I 0359
10625
r 0639
10646
4576
4619
4720
4868
4908
5348
5677
5679
5837
5992
6226
6378
6613
7061
7798
7803
7805
7819
7820
7833
8037
8229
8283
83 l6
AIS-1
AIS-1
AIS-1
AIS-I
AIS-1
AIS-1
AIS-I
AIS-I
AIS.1
AIS-I
AIS-1
AIS-I
AIS-1
AIS-1
AIS-1
AIS-1
AIS-I
AIS-1
AIS-1
AIS.1
AIS-1
AIS-I
AIS-I
PS-I
PS-1
PS-1
PS-1
PS-1
PS-I
PS-I
PS-1
PS.I
PS.1
PS-1
PS-1
PS-1
PS-I
PS-1
PS.1
PS-1
PS-1
PS-I
PS-I
712212002
11112003
31t912003
611312003
71y2003
121112003
12t1t2003
31112004
31312004
412712004
711712004
811612004
111812004
1U1512004
61112005
10111200s
7t26/2006
1012712006
11/1/2006
1212212006
411012008
4t29t2008
st30/2008
121U1996
tzlUt996
U1lt997
3lUt997
3151t997
71311997
10/6/1997
101711997
t113lt997
211311998
5/14/1998
812511998
1211411998
4120t2000
sl30t200t
sl30l200t
sl30l200t
513012001
st30t200t
611412001
713112012
1213112012
313112013
611312023
613012013
1U3012013
711l20tt
212812014
31312014
4t3012014
613012014
713112014
1013U2014
1013112010
513112015
91301201s
7 tzst20t1
1013112011
1013112010
1213112010
4t30t2018
4t30t2018
s/31/2018
t2l3U20t0
1213112010
1213112010
12t31t2010
1213112010
1213112010
1213112010
1213112010
slr712010
1213112023
1213112010
12/31/2010
1213112010
4t20t2020
1213112021
12t31/2021
12t31/2021
12131/2021
1213112021
61812020
PS-I
PS-I
PS-I
PS-I
81212001
11812002
3114t2002
411112002
8t31t2021
U3112022
3t3U2022
413012023
Docket No. RP I 5-l 294-000
Accepted: October 23, 2015
Page 66 of 96
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
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 Enerry LLC
Select Natural Gas LLC
Tenaska Marketing Ventures
Cargill, Inc.
United Energy Trading, LLC
Apache Corporation
Occidental Energy Marketing, Inc.
Tenaska Marketing Ventures
California Dept. of Water Resources
Devon Canada Marketing Corporation
Merrill Lynch Commodities, Inc.
Pacific Summit Energy LLC
Louis Dreyfus Energy Canada LP
Louis Dreyfus Energy Services L.P.
Devlar Energy Marketing, LLC
Suncor Energy Marketing Inc.
J.P. Morgan Ventures Energy Corporation
CanNat Energy Inc.
Eagle Energy Partners I, LP
Sequent Energy Management LP
El Paso Ruby Holding Company, LLC
Portland General Electric Company
8324
8340
8406
8534
8s39
8595
8652
8668
8784
8873
8886
8923
901 8
9173
9263
9273
9584
9772
9948
10195
103r0
10332
12071
17293
PS-1
PS.1
PS-1
PS-1
PS-1
PS-1
PS-I
PS-I
PS-I
PS-1
PS-I
PS-I
PS-I
PS-I
PS-I
PS-1
PS-1
PS-1
PS-I
PS-I
PS-1
PS.1
FTS-I
FTS-I
411612002
51212002
712212002
1111512002
121U2002
311912003
s12312003
'7 t1t2003
9t10t2003
121112003
121112003
21112004
41712004
813012004
1012912004
111412004
s121200s
10t1t2005
21112006
7/2612006
1012712006
1U112006
111U2012
1013112015
413012022
s131t2022
713U2012
10t31t2012
tU30l20t2
313112013
513112013
613012013
813U2013
11t30t2013
71U2011
113U2014
41712014
813012010
1013U2010
1013112014
413012015
91301201s
113U2016
712512011
1013112011
10/31/2011
3t31t2018
t0l3U204s
Issued: September 25, 2015
Effective: October 26, 2015
2017 Attachment D Pipeline Tariffs
Docket No. RP I 5-l 294-000
Accepted: October 23, 2015
Page 67 of 96
Gas Transmiss ion Northwest Corporation
Fourth Revised Volume No. 1-A
Table of Gontents
Fourth Revised Volume No. 1-A
1 TABLE OF CONTENTS
2 PRELIMINARY STATEMENT
3 MAPS
4 STATEMENT OF RATES
4.1 FTS-1 and LFS-I Rates
4.2 ITS-1 Rates
4.3 Footnotes to Statement of Effective Rates and Charges
4.4 Reserved For Future Use
4.5 Parking and Lending Service
4.6 Negotiated Rate Agreements - FTS-1 and LFS-1
4.7 Footnotes for Negotiated Rates - FTS-1 and LFS-1
4.8 Negotiated Rate Agreements - ITS-1 and PAL
4.9 Footnotes for Negotiated Rates - ITS-1 and PAL
4.10 Non-Conforming Service Agreements
5 RATESCHEDULES
5.1 Rate Schedule FTS-1 - Firm Transportation Service
5.2 Rate Schedule LFS-1 - Limited Firm Transportation Service
5.3 Rate Schedule ITS-1 - lnterruptible Transportation Service
2017 Attachment D Pipeline Tariffs Page 68 of 96
Gas Transmission Northwcst l-L('
FIrRC Gas TarilT
Fourth Rr"'viscd Volunrr.' No. l-A
TABI-E OF C'ON]'I]N1-S
PART I
TABLIJ OI: CONTENTS
v.9.0.0 Supcrscding v.8.0.0
Section No.
Preliminary Statement...
System Map...........
Statement of Ralcs
FTS-l antl LFS-l Rate-s........
.....2
3
4.1
ITS-l Rates 4.2
Footnotes lo Statcmcrrt of Effective Rates and Chargcs................. ..............4.-3
Reserved F'or Futurc Use 4.4
Parking and Lending Scrvice.......4.-s
Negotiated Rate Agreenlcuts - FTS-l and l.F'S-l 4.6
Descriptiott
l'ablc' ol'Conterrls .
FTS-I
LFS-I
tTs-t
I.JSS.I
PAL
Footnoles lbr Ncgotiated Ratcs - FTS-l and LFS-l ,...........
Negoliated Ratc Agrccmcttts - [TS-l and PA[-
Footllotes for Negotiated Rates - ITS-l and PAL.....
Non-Coufomring Scrvice Agrccmcnt ........
Ratc Sclredules
.......4.7
.....,.,.,4,9
4, t0
4.8
5.2
_s.3
lssuctl: Septcnrber 25, 201-5
Ef'fcctir e : Octobcr 16. l0l5
2017 Attachment D Pipeline Tariffs
( Firnt Transportatiun Scrvice)
( Linritcd Firnr'Iransportation Scrr icr.).
( lntcrruptiblc Transporlation Scrvicc)..
( Unhundled Sales Servicc) ...................
(Parkirrg and Lc'nding Sen'icc)
5.4
5.5
I)ocket No. RP I -5- I 294-000
Acceptcd: 0ctobcr 23. 201 5
Page 69 of 96
Gas'l'ran.smission Norlhwcst l"l-('
FIIRC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I l. 20ll
Iifl'cctive': April4. 201 I
2017 Attachment D Pipeline Tariffs
PART 4
STATEMENT OF RATES
v.2.0.0 Supcrseding v. 1.0.0
STATI]MENT OI. RATI]S
Docket No. RP I l- l9tl6-000
Acccptcd: May4. 20ll
Page 70 of 96
Gas Transmission Northwcst I-I-C
FIIRC Gas Tarill
Fourth Rcviscd Volumc No. l-A
DAILY
MILEAGH (a)
(Drh-MILE)
BASE 0.000434 0.000000
STF (c) (c) 0.000000
EXTENSION CHARCIlS
MF.DFORT)
E-l (i) 0.00275e 0.000000
E-2 (h) 0.002972 0.000000
(Diamond l)
E-2 (h) 0.001166 0.00000(l
(Diamontl2)
(.OYOTti SPRINGS
E-3 (i) 0.00121t2 0.000000
CARI'Y LATIRAL
Il{ (p)
0VERRUN CIIAR(;L fi)
StlR('tlAR(il:S
A('A (k)
lssuetl: Novcntber 24. 201 5
Ellcctive: .fanuary l. 2016
2017 Attachment D Pipeline Tariffs
PART 4.I
4.1 - Statement ol'Rales
FTS-l and LFS-I Ratcs
v. I 5.0.0 Superseding v. I 4.0.0
S'I'A'TIMENT OF EFFECTIVE RATES AND CIIARGES FOR
TRANSPORTATION O}' NA'TURAL GAS
Ratc Schcdulcs FTS-I and LFS-I
RIISITRVATION
MaI-MrL Max. Min.
DAILY
NON-Mll,l1AGF. (b)
(Drh)
DELIVERY (c)
(Drh-Mll-E)
&t------l4tn.
0.00il)16 0.0()00t6
0.000016 0.000016
FUEI. (d)
(Drh-Mll.E)
Max. Min.
0.0050% 0.0000%,
0.0050,1.1, 0.0(x10,,,i,
0.034.193 0.000000
(c') 0.000000
0.(xr464t 0.(xx)000 0.000026 0.0(xn26
0.(x)0000 0.000000
0.00(xl(xt 0.00(m00
0.(xtlltt.l 0.o(xxxm 0.0()0000 0.0rxx,(x)
tl.l6(1475 (1.(XX)(XX, (,.000000 0.O(XXXI)
(k) (k)
Dockct No, RP I 6-235-000
Acceptcd: I)eccmbcr .30. 201-5
Page 71 of96
Cas Transmission Northwest LLC
FIIRC Gas TarilT
Foulh Rcviscd Volumc No. l-A
RASTJ
MILEAGE (n)
(Drh-Mile)
Mux. Min.
(e) O.0(XXNX)
I:XTENSION CHARGES
MEDFORT)
b-l (Medlbnl) (l)
0.002759 0.000000
COYOTN SPRIN(;S
E-3 (Coyote Springs) (it
0.001282 0.000000
CARTY I-ATERAL
E4 (Carty Lateral) (p)
STJRCHARCES
ACA (k)
NON-MILEAGE (o)
(Drh)
Max. Min.
(e ) 0.0(X1000
DELIVERY (c)
lDth-Milc)
Max, * Min.
0.0{)00t6 0.000(}t6
PART 4,2
4.2 - Statenrcnt ol'Ratcs
ITS-l Ratr:s
v.6.0.0 Superscding v.5.0.0
F'UIiL (d)
(Dth-Mile)
Max. -MirU
0.0050?0 0.0000%
STATEMENTOF EFFE('TIVE RATES AND CIIARCES FOR
T'RANSPOITTATION OF NATURAL GAS (a)
Ilatc Schcdulc ITS-l
0.004Mt
0.00128-3
0. I 66475
(k)
0.00ffm0
0.000000
0.0(x)0(10
(k)
0.000026
0,000000
0.00m00
0.000026
0.000000
0.000000
Dockct No. RPI 6-109-000
Accepted: I)ccenrber 22. 201 5
Page 72 of 96
lssustl: Novcntbsr 20. 2015
Illfective: Jartuary l. l0l6
2017 Attachment D Pipeline Tariffs
Gas Transrnission Northwcst LLC
FERC: Gas Tariff
Fourth Rcviscd Volumc No. l-A
PART 4.3
4.3 - Statement of Rales
Footnotcs to Slatcmcnt of Effcctivc Ratcs and Chargcs
v. I 3.0.0 Superseding v. I 2.0.0
STATEMENT OF EFFE('TIVE RATES AND CIIARGES
}..OR']"RANSPORTATION OF NATURAL C}AS
Notcs
(a) Thc milcagc componcnt shall bc applicd pcr pipr'linc nrilc to gas transported by GTN for
delivery to shippcr hascd on thc primary receipt and delivery points in Shipper's contract.
Consult GTN's syslcrn rnap in Scction 3 for rcccipt arrd dclivcry point and nrilcpost
desig;nations.
(h) The non-nrilcagc componcnt is applied per Shipper's MDQ at Prinrary Point(s) of Delivery
on Mainline Facil itic's.
(c) The delivcry ratcs are applied per pipeline nrile to gas tran.sportcd by CTN lbr dclivery to
shipper lrased on distancc of gas transportcd. Coruuh GTN's syslenr rnap in Section 3 for
reccipt and delivery point and nrilepost designations.
(d) Fucl Usr,.: Shipper shall tunrish gas used for comprcssor station fhc!, Iine loss. and other
utility purposes. plus other urraccunrrlcd-for gas used in the operation ol GTN's combined
pipelinc system in an amount cqtml to lhe .sum of the current fucl and linc loss pelccrrtagc
and the l'uel and line loss percentagc surchargc in accordance rvith Scction 6.-1ll ol'this
tnritT. rnultipliu'd by tlrr,' distancc in pipclinc rnilcs transportcd fronr thc rcccipt point to thc
delivery point nlultiplied hy the transportation quautities of gas received fronr Shipper
undcrr thcsc ratc schcdulcs. The current fuel and line loss percentage shall be adjusted caclr
month lrclween thc maximum riltc of 0.0050%r pr-r Dth per pipeline mile and the mininrunr
rate of 0.000001, pcr Dth per ntile. The tuel antl line loss percentage.surchargc is 0.0002%,
per Dth per pipeline milc. No luel usc chargcs s'ill be assessed for backhaul sen,ice.
('urrcrrtly ctfbctivc' lirel charges nray lre tburrcl on Ci'l'N's lntcrrret wcbsitr. undc'r
"lnfonrtalional Postittgs. "
(c) Scasonal recoursc rates apply lo short-le"nn llrnr (STF) scrvicc urrdcr Rate Schcclulc FTS-l
(i,e.. linn scrvicr.' that has a tcnn of less than onc year and that docs not include urultiple-
yL.ar sL'ilsonalsen'icc) and l'l'Scrvicc undcr Ratc Schcdulc ITS-1. By March I ol-each year
(iTN rnay designatc up to fbur (4) nronths as peak months during a lnelve-mnrrth pcriocl
bcginning on Junc I of tlre silrnc ycar through May 3l of the ftrllowing ye-ar. All other
months rvill bc considcrctl s1|'-pcak moutlrs. Resenation ralc conrponcnts thilt apply to
STF scrvicc and pcr-unit-ralc l'l' scn,icc arc as follows (dclivcry chargcs and applicablc
surcharges continttc to apply):
4 Pcnk
Mos.
$0.048150
$0.0(x)6011
i Pcak
Mos.
5;0.04n I 50
$0.(xx)608
2 Pcak
Mtts.
$0.04tt l-s0
$().(m0608
I Peak
Mo.
$0.048 !50
s0.00060tt
0 Peak
Mos.
$0.034393
$0.000434
Peak Nt\4 Res.
Pcak Mi. Rcs.
lssuctl: Novcntber 21. 2016
Effc'ctive: .lanuary l. 2017
2017 Attachment D Pipeline Tariffs
Docket No. RPlT-l tt8-000
Acccptcd: Dcccmbr:r l-1, 2016
Page 73 of 96
Gas Transurissior: Northwc'st LLC
I"DRC Cas Tariff
Fourth Rcviscd Volurnc No. I -A
Off-Pk NM Rr,'s.
Off-l'k Mi. Rcs.
PART4..1
4.3 - Statement ol'Rates
Footnotcs to Statcnrcnt of Effcctivc Ratcs and Clhargcs
v.I -1.0.0 Superseding v.l 2.0.0
s0.0275 t 5
$0.000347
s0.029807
$0.000376
$0.03 r 642
$0.000399
s0.033 t42
s0.000418
$0.034393
$0.0004-j4
Months currcnlly dusignatcd as "Pcak Months" nray bc found on GTN's lntcmct wcbsitc
under "lnlbrmational Postings." By March I of each year. CTN will post thc Peak Months
fbr tlrc upcoming twclvc-rnonth pcriod bcginrring Junc I of thc sarnc ycar.
(f) Applicablc to finn scrvicc on (iTN's Metlford Extr.rrsion.
(g) Rcsctvcd for Futurc tjsc.
(h) E-2 (Diarnond I ) is a ncgotiated reservation charge of $0.002973 per Dth per day tbr t'irst
4-5.000 Dth/d and [-2 (Dianroud 2) is a negotiated reservalion churge ol'$0.001166 per Dth
per day for the sccortd 45.000 Dth/d, Durirtg leap years. E-2 (Dianrond l) is a rrr.gotiated
reservation charge of $0.002964 pcr Dth per day for first 45.000 Dth/tl and E-2
(Diarnond 2) is a negotiatetl reseryation charge of $0.001 163 per Dth pcr day tbr lhe second
45.000 Dth/d.
(i) Applicable to finn service on GTN's Coyole Springs Exlension.
(it The Overrun Chargc shall bc cqunl lu the ratcs uud charges sct li)rth lor intcmrptiblc sulvicc
undcr Ratc Schcdulc ITS-l.
(k) ln accordance with Section 6.22 of thr: Transportation Ccncral Tenus antl Contlitiorrs of this
FERC Gas'l'ariff. Fourth Rcviscd Volurue No. l-A. allTransporlation scrviccs that irrvolvc
thr: physical nrovettrent of gas shall pay an ACA unit adjustnrent. Tlre cutrently cft'ective
A('A unit adjusttncnl as puhlislrc'd on the ('onrnrissiorr's ncbsitc (w!ru-lr":r ,sov) is
incorporated herein by reterence. This adjustrnent shall bc' in adtlition lo the Base TaritT
Rate(s) specified abovc.
(l) Ru'served fur Futurc Usc'
(rn) Resened.
(n) The Rale Schedule ITS-l Milcagc Cotnpottcnt shall he applicd pcr pipclirrr' nrilc to gas
transpotlcd by GTN trased on thc distancc ol'gas transportcd. Consult GTN's systcnr nrap
in Scction .j ftrr rcccipt and dclivcry point and ruilcpost tir:signations.
(o) Thc Ratu Schcdulc ITS-I Non-Milcagc ('onrponcnt shall bc applir:d pcr Dth ol'gas
trflnspoled by CTN lbr irnntctliatc delivcry to tlre facilities oIanothcr entity or an cxlc]lsion
facility.
(p) Applicable to lirnr scnrit'c un (i'l'N's ('arty Lntcral Extcnsion.
lssuctl: Novenrber 21. 2016
Etll'ctivc: .fattuary l, 20 1 7
2017 Attachment D Pipeline Tariffs
Dockel No. RI'l 7-l ti8-000
Acceptcd: f)ecember 13. l0l6
Page 74 of 96
Cas Transnrission Nortltwcst LI-C
I'-ERC Gas Tariff
Foufih Rcviscd Volumc No. l-A
lssuccl: May 26. 201 I
Ilfl'cctivc: .lunc 27. 20ll
2017 Attachment D Pipeline Tariffs
PART 4.4
4.4 - Statement o[Rates
Rcscrvcd For Futurc Usc
r'.3.0.0 Superscding v.2.0.0
RDSTiRVIJD 1.'()R ITIJ'I'URE USE
Dockct No. RPI l-2132-(X)0
Acccplcd: .lunc 10, 201 I
Page 75 of 96
Gas Transmissiorr Northwcst LLC
IjURC Gas Tarill'
Fourth Rc'viscd Voluntc No. l-A
lssuetl: Novcnrber 20. 2015
[:fli;ctir,e: .lantnrl' l. 2016
2017 Attachment D Pipeline Tariffs
PART 4.5
4.5 - Statement of Rates
Parking arrd Lcnding Scrvicc
v.6.0.0 Superseding v.5.0.0
STATEMENT OF EFFECI'IVE RATES AND CI{ARGES
FOR TRANSPORTATION OF NATURAL GAS FOR
Parking and Lcnding Scrvicc
($/Dth)
BASE TARI}'F RATE
MINIMUM MAXIMTJM
PAL Parking and Lentlirrg Servicr':
Notcs
0.0 0.24354 r/d
Dockct No. RPI 6-109-000
Acceptcd: I)ecernbcr 22. 2015
Page 76 of 96
Gas Transnrission Noflhwcst LLC
FERC Gas Tariff
Fourth Rcviscd Volunrc No. l-A
PART 4.6
4.6 - Stalenrent ol'Rates
Nr.-gotiatcd Ratc Agrecnrcnls - FTS-l and LFS-l
v.4.0.0 Superseding v.3. 1.0
STATI]MIINT OF EFFECTIVI] RATES AND C}IARGES
FOR TRANSPORTATION OF NATURAL (iNS
NEGOTIATED RATE ACREEMENTS UNDER RATE SCHEDULES }'TS.I AND LFS,I
SHIBPER
Avista
('orporation /l
I'owerex Corp./ I
]'EI{M Ol-'
('oN'tRA('T
RATE
S('IlEDULI:DTHID
20.000
PRIMARY
RECI;IPT
POrNl'
PRIMARY
DIiLIVEITY
POINT
RATE
/2 i3
ll/l/01 -
lot3ll25
l-TS-l Medlbnl Mcdford Ext.
Mcter
l7
04101/l(r -
I 0r3 t/t 6
FTS-I 20.000 Kingsgate Malin t5
lssuctl: April l. 2016
Effcctivr': April l. 2016
2017 Attachment D Pipeline Tariffs
Dockcl No. ltP I 6-794-000
Acceptcd: April 26, 2016
Page 77 of 96
Cas Transnrission Norllrwcsl [,LC'
FERC Gas Tarilf
Fourth Rcviscd \rolume No. l-A
PART 4.7
4.7 - Statenrent ol'Rates
Footnotcs for Ncgotiatcd Ratcs - FTS- I and LFS- |
v.6.0.0 Supcrseding v.5.0.0
STA'TIIMINT OF [FFE("TIVE RATES AND CIIARGES
FOR TRANSPORTATION OF NATURAL CiAS
Ncgotiatcd Ratc Agrecrncnts tJnde-r Ratc Schcdulcs FTS-l and LF-S-l
lixplanatory F'ootnotcs f'or Ncgotiatcd Ratcs
tuudcr Rate Schedules FTS-l and l-FS- I
ll This contract does not dcviate in any material aspect from tlre [onn of Service Agreement
in this Tariff.
12 Unless otherwise noled. all Shippers pay Ci"l'N's nraximunr Reservalion Charge, Delivery
Chargc. ACA. and oorttrihute ficl in-kind in accordance with this TaritT.
13 Indcx Pricc Rcfr-rcnces: Unless olhcrwise uoted. rcferences tn "f)aily Index Price" shall
nrean tlre price survey ruidpoint for the specified point as published in Cas Daily tbr the
day of gas flow. Wcckcrrd and holiday prices u,il[ be delernrinetl using the next availablc
Cas Daily publication. Unless otlrerwise noted, the ret-ercnces to the "NGl IrOM" for il
specifictl poiut shall mcan Natural Cas Intelligerrce'.s First of Monlh Bitl Week Surve'y
(Supplenrent to NGI's Weekly Gas lndex) Spot Cas Pricc for thc spccificd point.
t4 Rcscrvud
/5 GTN and Shipper lrave agreed to a Fixetl llcservation Rate Charge of $0.26300 inclusive of
the milcagc and rron-milcagc compoucrrts. which shall be applicable to the Prirnary Rcceipt
arrd Delivery Points as rvell as secondary;rnints, as ltrllorvs:
Secondary Receipt Points: All puints on (iTN's syslenr
Secrrndary Dr"livery Poirrts: All points orr GTN's syslern
lrr adtlition, Shipper slrall pay all applicablc churgu's and surcharges ir: accordarrcc with
CTN's F-ERC Cias Tarit'f.
Reserued
The Reservation chargc shall be cqual to the mte set lbrth in GTN's F'ER( Cas Tariff
idcntificd as FT'S-l I1-2 (WWP). or its suL:cLlssor. multiplicd by thc appropriatr"'Effcctivc
Period Percentagc as shown in thc I'ollowing tablc.
t6
t7
Ell'cctive Pcriotl
I l/l/01-t0r3l/02
I llt()2-10/31/03
I l/ I /03- l0r-3 li 04
I l/ lr04- l0i 3 l/()5
Percentagc
75,%
80%
fl504
90%,
lssued: April 1.2016
Efl'cctivr-': April I . l0l 6
2017 Attachment D Pipeline Tariffs
Dockcl No. RPI 6-794-000
Accr'ptetl: April 26. 2016
Page 78 of 96
Gas Transmission Northwcst LLC
F'ERC Gas Tariff
F'ourth Rcviscd Volumc No. l-A
I r/l/05-l0i3l/06
|/u06-10t3U25
lssucd: April l. l0l6
Efll'ctivc: April l. l0l6
2017 Attachment D Pipeline Tariffs
PART 4.7
4.7 - Statenrent of Rates
F'ootnotcs for Ncgotiatcd Ralcs - FTS- l and LFS- l
v.6.0.0 Superseding v.5.0.0
95%
l00o/o
Thc Daily l)clivcry Chargc shall bc u-qual to thc 100% load factor cquivalcnt of thc l"TS-l
Ij-2 ratc. or its successor. and shall be nurltiplied by the positive difference bctwcen (a)
volumcs dclivered and (b) the contract MDQ times the appropriatc liffcctivc Pcriod
Percentage.
Daily Delivery C'hargc - [Dth Dclivered - (MDQ + I]ffective Period %)l * 100% Load
Factor Equivalent FTS-l E-2
18 Reserved
19 ReservE'd
llll Rescrved
ll I Rgscrucd
l12 Rcscrvcd
/l-3 Rcscrvccl
tl4 Reserved
/15 Rest'rvcd
il6 Rcservcd
ll7 Rcscrvecl
/ltt Rcservecl
Dockel No. Rl' | 6-794-000
Acccptctl: April 26. 201(r
Page 79 of 96
Gas Transmissiorr Northrvcst LLC
FERC Gas Tariff
Fourth Rcviscd Volumc No. l-A
PART 4.Ii
4.8 - Statement of Ratcs
Negotiatcd Rate Agrccnrents - ITS-l and PAL
v.5.0.0 Superseding v.4.0.0
STATEMENT 0F EFFI:CTIVE RATES AND CIIARGIIS
FoR TRANSPORTATION OF NATI.IRAL CAS
NEC]OTIATHD RATE AGREEMENTS UNDER R TE S(:IIEDULE ITS.I AND PAL
SI IIPPIIR
]'ERM Ol.
(.oNTRA('T
PRIMARY
RE('IIIPT
POINT
PRIMARY
DELIVNRY
POINT
RAI'E
sclrEplJLE DTE/[
RATN
j3 r3
Issuetl: April 24.2015
Effectiye: .hrne l. 201-5
2017 Attachment D Pipeline Tariffs
[)ockct No. RPI 5-905-000
Acccptctl: May ?9. 2{)l-5
Page 80 of 96
Gas Transruission Nortlrwcst LLC
I"ERC Gas'l'ariff
Fourth Rr,'viscd Volumc No. l-A
lssued: April 24.201-5
[ffcctivc: .lurrc l. 2015
2017 Attachment D Pipeline Tariffs
PART 4.9
4.9 - Statcment ol'Rates
Footnotcs for Ncgotiatsd Rates - ITS-l and PAL
v.5.0.0 Superseding v,4.0.0
Docke'l No. RP I 5-905-000
Acccpted: May 29. 2015
Page 81 of96
STATEMENT OF EFFECTIVE RNTES AND CIIARGES
}.OR TRANSPORTATION O}' NATURAL GAS
NEGOTIATITD RATE ACITEEMENTS UNDIIR RATE SCHEDULE ITS-I AND I,AL
Explanatory Footnotcs fbr Ncgotiatcd Ratcs undcr Ratc Schcdulc ITS- l and PAL
ll This contract does not deviate in any nraterial aspect from the Form of Service Agreenrenl
in this Tariff.
12 Unloss olhenpisc noled" all Shippers pay GTN's nraximurrr Mileage and Nolr-Mileage
Charge. A('A. arrtl contribute ftrel irr-kind in accordance with this Tariff.
13 lndex Price References: Unless otherwise noted. references to "f)aily Iudcx Pricc" shall
rncan thc pricc survcy midpoint for the specilied point as publishcd in Cas Daily lbr the day
of gus flow. Weekertd aud holiday prices rvill be detemriued usirrg the next availablc Cas
Daily publication. Unlcss othcrwisc noted, the rclbrerrccs to thc "NGl l.'OM" for a spscitied
point shall nrean Nalural Gas Intelligence's Firsl of Month Bid Week Survt'y (Supplcnrcnt
to NGI's Wcc'kly Cas lndex) Spot Cas Pricc lbr tlrc spccil'icd point.
Gas Transn:ission Northwcst LLC
FERC Gas Tarill'
Fourth Rcviscd Volumr,' No. l -A
Nanre ol'Shinner
PART 4. I O
4.10 - Stalement of Rates
Non-Confonning Scn,icc Agrecmcnts
v.4.0.0 Supcrscding v.3.0.0
NON -CONFORM IN(i SERVICE ACREEMENTS
PTJRSIJAN'r'TO S r54.r r2(b)
('ontract
Nunrbc'r
Rate
Schr:tlulc
Ellectivc
Date
Termination
Date
Cascadc Natural Gas Corporatiott
Chcvnrn USA lnc.
City of tsurbank
lGl Resourccs. lnc.
Northenr ('al ilbnriu Powcr Agcncy
Talisnran Energy lnc
Pararnounl Resources US lnc.
Pctro-('unatla I lydnrcarbons. lttc.
Sacranrcnto Municipal Utility District
Avista Corporalion
Avista Corporation
Cascadc Natural Cas Corporation
Northwcst Natural Cas Conr;rany
Puget Sound Encrgy. Inc.
Avista Corporalion
Avista C'orporalion
Avista Corporalion
Avista Ourporalion
lbcrdrola Rcncwablss. lnc.
Avista Corporation
Pacific Gas and Hle'ctric ('onryany
Northwcst Natur:rl Gas (iunpany
Pctro-('anada I lydrocarhons. lttc.
Morgan Starrlcy ('apital Group lnc.
Shell Eneryy Norlh Anrcrica (USt. l,.P
BP Canada Ent-'rgy Markcting ('orp.
Scmpra line'rgy Truding ('orp.
EnCana Markcting (LISA) Iuc.
Ncxcn Markctirtg Ll.S.A.. lnc.
Shcll Energy North Anrc'rica (US). l-.P
Sicn'a Pacific Pou,cr' ('ompany
('ity ol'(ilcndulc
lherdrola Renervables. lnc.
Petro-Canatlir I lydrocarbons. lnc.
Chcvron U.S.A. lnc.
Snhnon Rusourcr:s l-ld.
('onstcllalion Incrgy Cottunodilir's
(iroup. lnc.
Ensr,'rco Ent-rgy lrrc.
C'onw'oPhiII ips Cornpany
UBS AG (l.turtlon Brnnch)
FTS.I
FTS.I
r-'TS-l
FTS.I
FTS-I
FTS-I
rTS.I
FTS-I
FTS-I
t 1's-l
l.-Ts-r
FTS.I
FTS.I
FTS-I
tTS-l
FTS-I
IrTS-l
l;'l's-t
l.'1's-t
FTS-I
ITS.I
ITS-I
ITS.I
t't's-l
t't's-l
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
I t/l/t993
I t/l/t991
I t/l/te93
t t/l/1993
I l/t/1993
I l/t/teel
llnlte93
I t/l/1e93
ll/l/199-1
lli t/199.1
ll/t/t99.1
I ti t/r9e3
I l/t/1e93
I l/l/1e93
I t/r/r991
ni I /t 995
I t/l/t9e5
I t/l/t995
61_3/200 t
lli t/200t
lillt993
4ill1992
4t22/1q92
7!23/lqel
rJ/ t/ t99.1
l3/l/1996
I il /199'7
I r2-5/ I 997
6tl7lt99t)
4r I 0/200r)
4t2712000
5i 3(Y2(,(,1
5i 30/200 I
51.30/200 t
5i 30/200 I
51_101200 t
t(y3 t/2023
I 0/3 I /2023
l0i -1 I i1023
t0i3 ti20t3
r 0/_1 1i2023
l0/l 112023
l0i I t/2023
I 0i-l l/2023
|v3v21t2l
lol3ti?023
I 0r3 li 2023
I (y3 t/2023
l0r3 l/2023
I (y-r t/2021
r {}/3 ti2023
l(v3l/2025
l0/3 1i2025
t0i3 t/2(,2.s
l0/31i2()2-i
I 0/3 1i2035
t0i3l/20t0
3/31/20t I
4/?2t20ll
9/30/20 l 0
8/tr2()l()
l2l31/2(lt0
l2i -l I i20I 0
lli3titOt0
I3r3Iilot0
Ilr3Ii:0I0
I2i-li 2019
ll/lli202l
12i.1 t/202 t
l2i _t I i202 t
lli.l lil02l
t2/.] ti302 t
It0.1t(
Iil 76
tt22lt
Ir-l I t{
AIS-I
AIS-I
AIS.I
AIS-I
lt/2/?0(,1
n/27t200t
I i 8/2(Xr2
4l I t/2(X)2
8/3I r202I
I I/_10i202I
t/3U2022
4t30t21t23
lssuctl: Scptctnbcr 2.5. 201-5
Effcctive: October 26. 2015
2017 Attachment D Pipeline Tariffs
I)ocket No. RPI -5- I 294-000
Acccptctl: October 23. 20l5
Page 82 of 96
152
153
l-s4
l5tl
t63
l6'l
l6tt
t69
170
177
l7l{
179
I80
l8l
In2
259 !
l8-57
2858
7828
1t035ilt
I t2
lle
t44
146
462 I
1721
1770
6759
7047
706tr
7804
7n06
7lt07
78 t2
7816
Gas Transrnission Norlhwcst LLC
FERC Gas TarilT
Fourth Rcviscd Volunrc No. I -A
lssuctl: Septe nrbr:r 15. 2015
l.lffcctivc: C)ctotrcr 16. 20I 5
2017 Attachment D Pipeline Tariffs
PART 4.IO
4.10 - Statemcnt ol Rates
Non-Conforming Scn'icc Agrce'mcnts
v.4.0.0 Superseding v.3.0.0
('oncord lincrgy t.L('
Tenaska Markcting Vcnlurcs
('argill, Inc.
Mcrrill Lynch Conrnnditics. luc.
Apache Corpomlion
Tenaska Marketing Venlures
California Dept. of Water Resources
Unitctl lincrgy Trading. LL('
Selcct Natural (ias l-L(l
National F'ucl Markcting Conryany l.l-(l
liortis Encrgy Markcting & Trading CP
Powerex (iorp.
Louis Dreylirs Energy Scn,ir:cs l-.P.
Pacific Sununit [nergy LLC
Dcvlar Encrgy Marksting. t.LC
Suncor Encrgy lr,larketing lnc.
('anNat Encrgy lrtc.
Eaglc Encrgy Partners I. [,P
Scqucnt Encrgy Marngcrncnl LP
Occidcntal lincrg,y Markctiug. lnc.
NcxtEra lincrgy Power Marketing. LL('
Nalural Cas lixchange. Inc.
(iitigroup Energy lnc.
lGl Rcsources. lnc.
Macquaric ('ook Encrgy, LL('
Scmpra lincrgy 'l'ratling ('orp.
EnCana Markclitrg (USA) Inc.
Shcll Encrgl'North Anrcrica (US). L.P.
llusky Cas Markcting lnc.
Enserco l:ncrgy Inc.
National Jrucl Markcting (irnrpany [-LC
Unitcd States (i-vpsum C'onrpany
Northu,cst Natural (ias ('ompany
Chg'ron tJ.S.A. lnc.
San Diugo Grs & lllcctric (lontpany
Soutlrcnr ('rrlilbnria Gls ('txttpalty
Pugct Sound Energy. lnc.
I lcrnriston (icnerirting ('ornpany. [".P.
('ity ol'(.ilundalc
lberdrola Renervahles. lnc.
Qucstar l'.nerg1' Trading Company
El Paso linergy Markctittg (ionrpany
Sclnpra l:ncrgy 'fradirrg ('orp.
('onstcllatiorr E ncrgy ('ontmodilics
(iroup. lnc.
C'onocoPhill ips Contpnny
'l'raclehel lincrgy \4urkcting. lnc.
UtsS AG (l.ontlon Brunch)
842 I
855e
8594
8674
8670
81ili0
8trtr7
e002
8978
9035
9t l5
9t49
92til
9285
9630
9774
t0t97
I 0308
I 0336
I 0359
I 0625
l 0639
I 0646
4576
;1619
1720
4868
.1908
5-141t
5677
567e
-5tt-17
5992
6226
6-178
661 3
70(r I
779t1
78()3
7t{05
7n l9
7820
7833
AIS-I
Ars-l
AIS-I
AIS.I
AIS.I
AIS-I
AIS-I
AIS-I
AIS.I
AIS-I
AIS-I
AIS-I
AIS-I
AIS-I
AIS.t
AIS.I
Ars-t
Als-l
AIS.I
AIS-I
AIS.I
AIS-I
AIS.I
lrs-l
PS.I
PS-I
PS-I
PS-I
PS-I
lrs-l
PS-I
PS.I
lrs-l
PS-I
PS-I
PS-I
PS.I
lrs-l
PS-I
PS-I
PS.I
PS-I
PS-I
7t22/2002
uv2003
.]i t9/2m.1
('/13/2003
7il1201)3
l2/112001
l2/v2003
3fi/2004
3t3/2004
1t27t?(JiJ4
7tl7latxM.
tt/ l(r/2004
I l/8/20M
I t/I512004
6l I /200-5
t0/l/200-5
7t2612006
10t27t2006
I t/t/2006
l2t22i2{to6
4lt0l200tr
4t29l2at0&
5i30/2(X)8
12il11996
t2lt/1996
Itlnq97
3t I / t997
3/5/ I r)97
7/3^997
lDt(ltL)97
lo/7llqe'l
nt3ile97
li l3/l99fi
5i l4l I 998
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Page 83 of 96
PS-I
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Gas Transrnission Northwcsl LLC
I"URC Gas TarilT
Fourth Rcviscd Volumc No. I -A
Issucd: Septenr[rc'r 25, 201 5
Eflectivc: ()ctohcr 16. ?()l5
2017 Attachment D Pipeline Tariffs
PART 4.IO
4.10 - Statement ol'Ratcs
Non-Confornring Scn,icc Agrccnrcnts
v.4.0.0 Superseding v.3.0.0
RWE Trading Anrcricas lnc.
Fortis Encrgy Markcting & Tradirrg CP
('oncord Encrgy LLC
Select Natural Cas Lt.('
Tenaska Marketing Ventutes
Cargill, lnc.
United lincrgy'li'ading. LLC:
Apachc C'orporatiort
Occidental Encrgy Markr:tirtg, Inc.
Tcnaska Markcting, Vculurcs
('aliftrrnia Dcpt. of Watcr Rcsourccs
Devon Canada Marketing Cbrporalion
Merrill Lynch Commodilies. hlc.
Pacific Sumntit Energy LL('
[.ouis Druylus Energy Canada LP
Louis Dreylirs lincrgy Scrviccs 1..P.
Dcvlar Hncrgy Mnrketing. LLC
Suncor Enr,'rgy Markcting lnc.
J.P. Morgan Venlures Energy Clo4roratiott
CanNat Iincryy lnc.
Eaglc Encrgy Partrrcrs l. LP
Sequent Energy Managentcnt l.P
[:l Paso Ruby llolding Company, l..LC
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Page 8.1
Effective Date: April 1,2014
Page 92 of 96
Westcoast Energy lnc.
TOLL SCHEDULES - SERVICE
TRANS PIORTATION SERVICE . SOUTHERN
DEFINITIONS
1. ln this Toll Schedule, the folloring term shall have the folbwing meaning:
APPLICATION
3.
(a)"@ m6ans Transportation Servica - Sor.rthern provided
pursuant to a Service Agreement under which gas is to be delivered to the
Huntingdon Delivery Area and, su$ecl to the fulfillment of the conditions specified in
the Service Agreement, to the Kingsgate Expoft Point;
"Kinosoate Exoort Poinf' means the point on the international boundary betrreen
Canada and the United States of America near Kingsgate, Bdtish Columbh, where
the Foothills Pipe Lines (South BC) Ltd. ftipeline facililies connect wih the pipeline
faciliUes of Gas Transmission Northwest Corporatbn; and
'SeMce Term' means in respecl of each Firm Transportation SeMce - Southem
specified in a Firm Service Agreement, the term of each such Firn Transportration
Service - Southem as determined in accordance with Seclion 3.
All other terms used in this Toll Schedule shall have the same meaning as set fodh in the
General Terms and Conditions.
(b)
(c)
2.This Toll Schedule applies to al! Firm Transporlation Service - Southem, AOS and
lnterruptible Transporlation Service - Southem, including lmport Backhaul Service, provided
by Westcoast on facilities in Zone 4 under the provisions of a Firm Service Agreement or an
lntemtplible 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 Servtce Agreement shall be
determined based upon the Service Term, and the SeMce Term for each such servbe shall
be determined as follows:
in the case of each Firm Transportation Service - Southem provided for in a Firm
Service Agreernent entered into by a Shipper with Westcoast prior to November 1,
2005, the number of whole years remaining in the term of each such service as of
November 1,2005;
in the case of each Firm Transportation Service - Southern provided for in a Firm
Service Agreement entered into by a Shipper with Westcoast after November 1,
2005, the number of whole years in the term of each such service specffied in the
Firm Service Ag reement;
in the case of each such Firm Transportation Service - Southern which is renewed
by a Shipper after November 1, 2005 in accordance with Section 2.06 of the
(a)
(b)
(c)
2017 Attachment D Pipeline Tariffs
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
4.
General Terms and Conditions, the number of whole years in the renevtral term of
each such serv'rce, with effect from the first day of the renewal term; and
(d)in the case of each Firm Transportalion Senice - Southem provided for in a Firm
Service Agreement which is exlended by the Shipper and Westcoasl afrer
December 31, 2005, the number of whole years remaining in the term of each srch
servic€, including the period of the extension. wi$r effecl from the firsil day of the
month immedidely following the execution by the Shipper of an amendment to the
Firm SeMce Agreement providing for such extension.
MONTHLY BILL. FIRM TRANSPORTATION SERVICE . SOUTHERN
The amount payable by a Shipper to Westcoast in respect of Firm Transportatbn SeMce -
Southem provkled in any month pursuant to a Firm Service Agreement shall be an amount
equal to:
(a) the produc{ 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 tax on fuel gas consumed in operations payable under the Mdor Fuel
Tax Act (British Columbia) and the Carbon Tax Ac{ (Brilish Columbia} which is
allocated to Shipper by Westcoast for the month,
less the amount of any Contracl Demand Credits to wtrich the Shipper is entitled for the
month pursuant to the GeneralTerms and Conditions.
MONTHLY BILL . AOS, INTERRUPTIBLE TRANSPORTATION SERVICE . SOUTHERN AND
IMPORT BACKHAUL SERVIGE
5.lf on any day Shipper has unutilized Firm Transportatbn Service - Southem at a Delivery
Point in Zone 4 and vtould incur on such day tolls for AOS and lntemrptible Transportation
Service, other than lmport Backhaul Service, at that Delivery Point or at any other Delivery
Point in Zone 4, then, notwilhstanding the provisions of the General Terms and Conditions
and for the sob purpose of determining the amount of the Commodity Tolls payable by
Shipper in accordance with this Toll Schedule for AOS and lnterruptible Transportation
Service - Sodhem, the following rules shall apply:
(a) firstly, in the case where Shipper would othen rise incur tolls on such day for AOS
and lntenuptibb Transportation Service - Southern at a Delivery Point where
Shipper has unutilized Firm Transportation Service - Southem, Shipper shall be
deemed to have utilized Firm Transportation Service at such Delivery Point on such
day in respect of a volume of gas not exceeding the volume of unutilized Firm
Transportation Service at such Delivery Point;
(b) secondly, in the case where a Delivery Point at which Shipper has unutilized Firm
Transportation Service - Southern is within the Huntingdon Delivery Area and
Shipper has any remaining volume of unutilized Firm Transportation Service at such
Delivery Point after applying the rule set qrt in paragraph (a) above, then Shipper
shallbe deemed to have made a diversion on such day pursuant to Section 7.01(a)
Page 8.2
Effective Date: April 1,2014
Page 93 of 962017 Attachment D Pipeline Tariffs
Page 8.3
Effective Date: April 1,2AU
Page 94 of 96
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
6.
of the General Terms and Conditions of a rolume of gas not exceeding the anount of
the remaining volume of unutilized Firm Transportation Servioe, fiom that Delivery
Point to any olher Delivery Point within the Huntingdon Delivery Area at whbtr
Shipper urculd othenrise incur tolls for AOS and lntenuptible Transportation Service -
Southem;
(c) thirdly, if Shipper has any remaining volume of unutilized Firm Transportation Service
- Southern at any Delivery Point afrer applying the rules set out in paragraphs (a)
and (b) above, then Shipper shall be deemed to harre made a diversion on such day
pursuant to Section 7.01(c) of the GeneralTerms and Conditions of a rdume of gas
not exceeding the amount of such remaining volume of unutilized Firm
Transportation Service from such Delivery Point to the nearest Downstream Delivery
Polnt at which Shipper would othenrise incur tolls for AOS and lntemrptible
Transportation Service - Southem; and
(d) fourthly, if Shipper has any remaining volume of unutilized Firm Tr:ansportation
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 Seclion 7.01(b) of the General Terms and
Conditions of a volume of gas not exceeding the amount of such remaanang volume of
unutilized Firm Transportation Service, frorn such Delivery Point to the nearest
Upstream Delivery Point at wtrich Shipper uould othenrise incur tolls for AOS and
lnterruptible Transportiation SeMce - Southern.
The amount payable by a Shipper to Westcoast in respect of AOS, lntenuptible
Transportation Service - Southern, and lmporl Backhaul Service provided on each day in a
month shall be an amount equalto the sum of:
(a) the producl obtained by multiplying the applicable Commodity Toll specified in
Appendix A for AOS, lnteruptible Transportation Service - Southem and lmport
Backhaul SeMce, respectively, by the Receipt Volume for such AOS or lntemrptible
Transportation Service - Southem (as determined afler applying the ruEs set out in
Section 5) or for such lmport Backhaul Service, respectively, at the point frqn which
the residue gas is sourced, which is thermally equivalent to the volume of residue
gas (i) delivered to or for the account of Shipper at the Delivery Point, or (ii)
transmitted through Zone 4 for the account of Shipper on each such day during the
month;
(b) the product obtained by mutiplying the difference between the Commodity Tolls
specifted in Section 7.03 of the General Terms and Conditinns by the volume of gas
deemed to be diverted to a Downstream Delivery Point in accordance with Section
4(c) on each such day during the month; and
(c) the amount of tax on fuel gas consumed in operations payable under the Motor Fuel
Tax Act (British Columbia) and the Carbon Tax Act (British Columbia) which is
allocated to Shipper by Westcoast for each day in the month.
2017 Attachment D Pipeline Tariffs
8.4
Effective Date: April '1,2017
Page 95 of 96
Westcoast Energy lnc.
TOLL SGHEDULES . SERVICE
APPENUXA
DEiIAND AI{D COMTODITY TOLLS
TRANSPORTATION SERVICE - SOUTHERN
Flrm Transportetion Seruice - Southem
Year Round Service
Demand Tolls
S103m3/mo.
FortisBC
Term
PNG
Deliwry Point
lnland
Delivery Area
Huntingdon
DdiwryArea
Kingwale to
Huntingdon*
l year 90.06 ZY.W 397.34 162.35
2 year 81.4 228.15 fi5.77 157.62
3 years 84.81 221.31 374.20 152.@
4 years 83,94 219.02 370.34 151.32
5 yearsor more 83.07 216.74 366.48 '149.74
' For Firm Transporiafrcn Service - Southem provided by W€stcoast pursuant to a Firm Servkx Agreement
dated April 15, 2002 betr,€en Westcoast and FortsBC Energy lnc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Garbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
Winter Firm Service
Demand Tolls
9103m3/mo.
Hqntingdon Delivery Area
WF Service
Novemberto March
Revertible WF
Service'Service Term
1 year 596.01 397.34
2 years 578.66 *5.77
3 years 561.30 314.20
4 years 555.51 370.34
5 years or more il9.72 366.48
' INF Service which has been designated as Rerrertible WF SeMce punuant to Section 23.'10 ot thc
General Terms and Conditions - Service to provide for firm tsansmission of rpsidue 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 (Brilish Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
2017 Attachment D Pipeline Tariffs
Westcoast Energy lnc.
TOLL SCHEDULES . SERVICE
AOS and lntenuptible Transportation Service - Southern
Commoditv Tolls
s/103;3
Months
PNG
DdawqPehl
lnland
DeliwrvArea
Huntingdon
Delivery Area
FortisBC
Kingsvale to
l'lcdrsdsrtl
April 1, 2017 to 2.947 7.691 13.004 5.313
Oc-tober 31,2017
November 1, 2017 to 3.929 10.255 14.304 7.0U
December 31,20'17
' For AOS provided by Westcoast puruant to a Firm Servioe Agreernent dated April 15, 20()!l betr^,een
Westcoast and FortisBC Energy lnc.
Plus the amo{Jnt of trax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
lmport Backhaul Seryice
Commoditv Tolls
ryl01;3
!nland
Delivery Area
PNG
Deliwrv Poit!!
Cornpressor
Station No.2
5.313 10.057 13.004
4.049 10.375 14.304
Plus the arnount of tax on fuel gas c.onsumed 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.
April 1, 2017 to
october 31,2017
November 1,2017 to
December3l,2017
8.5
Effective Date: April 1,2017
Page 96 of 962017 Attachment D Pipeline Tariffs
Months