20130731Exhibits A-D.pdf

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AVISTA UTILITIES
Case No. AVU-G-13-0 I
EXHIBIT O'A"
Proposed Tariff Sheets
July 30,2013
Nineteenth Revision Sheet 150
Replacing
Eighteenth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
natural gas, to become effective as noted below.
RATE:(a) The retail rates of firm gas Schedules 101, 111 and 112 are to be
increased by 48.148$ per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
37.3500, 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 10.7980, 37.3500, 48.1480,
Schedules 111 and 112 10.7980, 37.350C 48.1480,
Schedules 131 and 132 0.0000 37.350C 37.3500
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules 101 10.7440, 37.1640 47.9080,
Schedules 111 and 112 10.7440, 37.1640 47.9080,
Schedules 131 and 132 0.0000 37.1640, 37.164i,
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 by Avista UtilitiesBy- - f Kelly O. Norwood - Vice-President, State & Federal Regulation/4r{+ ar/n,^r6l
0
l.P.U.C. No.27
Nineteenth Revision Sheet 150
Replacing
Revision Sheet 150
lssued by
By
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To pass through changes in costs resulting from purchasing and transporting
natural gas, to become effective as noted below.
RATE:(a) The retail rates of flrm gas Schedules 101, 111 and 112 are to be
increased by BiaS$ per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
37.3500, per therm.
(c) The rate for transportation under Schedule 146 is to be decreased by
0.0006 per therm.
WEIGHTED AVERAGE GAS COST:
The above rate changes are based on the following weighted average cost of gas
per therm as of the effective date shown below:Demand Commodity Total10.798d, 37 350A, 48.148A
Schedules 111 and 112 10.7986, 37.350A 48.148d,
Schedules 131 and 132 0.000d 37.350d 37.350d
The above amounts include a gross revenue factor.
Schedules 101
Schedules 101
Demand Commodity Total10.744G 37.1646, 47.908A
Schedules 111 and 112 10.744G 37.1646, 47.908A
Schedules 131 and 132 O.0O0A, 37164A 37j646
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.
Avista Utilities
Kelly O. Nonrood - 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
in€,reased by W per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be inereased byW$, pertherm.
(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 l0l
Schedules lll and 112
Schedules l3l and 132
The above amounts include a gross revenue factor.
Demand Commodity Total
Schedules l0l
Schedules lll and 112
Schedules l3l and 132
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.
eigf+t€enth Revision Sheet 150
Replacing
S€\rente€nth Revision Sheet 150
Avista Utilities
Kelly O. Norwood - Vice-President, State & Federal Regulation
l.P.U.C. No.27
Fifteenth Revision Sheet 155
Canceling
Substitute Fourteenth Revision Sheet 155 155
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVA!IABLE:
To Customers in the State of ldaho where Gompany has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts geneeted by the souroes listed below.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
increased by 0.015C pertherm in allblocks of these rate schedules.(b) The rate of intemrptible gas Schedule 131 is to be decreased by
1.Uzi, pertherm.
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment and Schedule 156 -
Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued July 30, 2013 Effec'tive October1,2013
ncr ran{ hrr AuBy , Kelly Nonrood, Vice President, State & FederalRegulation4 J^,^-il
Fifteenth Revision Sheet 155
l.P.U.C. No.27
Canceling
Revision Sheet 155
AVISTA CORPOMTION
d/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of ldaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:(a) The rates of firm gas Schedules 101 and 111 are to be
increased by 0.0150 per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
1.0420, 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 and Schedule 156 -
Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
Avista Utilities
Kelly Norwood, Vice President, State & Federal Regulation
CORPORATION
Avista Utilities
AVISTA
dlbla
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
d€€feesed by +J#$ per therm in all blocks of these rate schedules.(b) The rate of interruptible gas Schedule 131 is to be decreased by
1€630 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 and Schedule 156 -
Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
lssued SeptembeF2ffi+3 Effective €r€teb€r-1++12
l.P.U.C. No.27
Sub€titut€nE€ud€€nth Revision Sheet 1 55
Canceling
Thirbenth Revision Sheet 155 155
lssued by
By
Avista Utilities
Kelly Norwood, Vice President, State & Federal Regulation
ao
AVISTA UTILITIES
Case No. AVU-G-13-0L
EXHIBIT'OB"
Notice of Public Applicant's Proposed Tariffs
July 30,2013
AVISTA UTTLTTIES
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.
Nineteenth Revision Sheet 150 canceling Eighteenth Revision Sheet 150
Fifteenth Revision Sheet 155 canceling Sub. Fourteenth Revision Sheet 155
Fifteenth Revision Sheet 155 updates the amortization rate used to refund or recover
previous gas cost differences and Nineteenth Revision Sheet 150 updates the forward-
looking cost of natural gas purchased for customer usage.
These tariffs request an annual revenue increase of approximately $4.9 million, or about
7.5%.
This request is a Purchased Gas Cost Adjustment (PGA) that is filed annually to reflect
changes in the cost of gas purchased to serve customers. Any increases or decreases
resulting from these PGA filings directly result from the cost of gas purchased in the
marketplace; Avista makes no additional profits from these rate changes.
If the Company's request is approved, the average residential or small commercial
customer using 60 therms per month will see an increase of $3.80 per month, or
approximately 6.8%. The present bill for 60 therms is $55.37 while the proposed bill is
$59.17. Larger commercial customers served under Schedules 111 can expect to see an
average increase of approximately 9.7oh, with the higher percentages due to lower base
rates. However, acfual customer increases will vary based on therms consumed.
This filing requests an effective date of October l, 2013.
Copies of the proposed tariff changes are available for inspection in the Company's
offices or can be obtained by calling [phone] or writing:
Avista Utilities
Attention: Manager, Rates & Tariffs
P.O.Box3727
Spokane, W A. 99220-37 27
July 30, 2013
AVISTA UTILITIES
Case No. AVU-G-13-0 ,
EXHIBIT 66C"
Workpapers
July 30,2013
Avista utilities
State of ldaho
Revenue Rate Change Sumamry
Based on 12 months October 1, 2013 - September 30,2014
Rate
une
No. Schedule Therms Change
Revenue
lncr (Decr)
r Ssbed.clc-EqreAlelolnellsl2 Rate Schedule 101
3 Rate Schedule 1u
4 Rate Schedule 112
5 Rate Schedule 131
6 Rate Schedule 132
7
8
9 Schedule 150 PGA Demand
10 Rate schedule 101
11 Rate Sch€dule 111
12 Rate Schedul€ 112
13 Rate Schedul€ 131
14 RateSchedule 132
15
16
17 Schedule 155 Amortization
18 Rate Schedule 101
19 Rate schedule 111
20 Rate Schedule 112
21 Rate Schedule 131
22 Rate schedule 132
23 Customer 1
24 Customer 2
25 Customer 3
26 Customer4
27 Customer 5
28
29
30 Total Chanse 150 & 155
53,084,075
23,62L,5r4
0
0
427,856
77,L33,446H
53,084,075
23,52r,5L4
0
0
427,856
77,L33,446
S
S
S
s
s
s
s
s
s
s
53,084,075 s
23,621,514 50s05
427,856 5
OS
OS0s0s0s
53,084,075 s
23,62L,5L4 50s
OS
427,855 5
0
0
0
0o'
0.04066 s
0.04056 s
0.04066 s
0.04056 s
0.00471 s
0.00471 s
0.00471 s-s-s
2,158,399
950,4s1
250,025
],t,2-57
0.m55_u_
I,L16,246
77,83,446
-161,zg30.01800 s
0.01800 s.S
0.00621 s_(-s-s-s-s
955,307
425,09s
ts,izst
(20)
(e)
0.05337 s 3,363,732
0.06337 s 1,496,803
0.04s37 s
0.04587 s
0.04055 s L7,397S (s,s2s)
s (20)
ss (e)s (10,372)j-@
s
$ 48s8,ooo
31 Rate fthedule 101
32 Rate Schedule 111
33 Rate schedule 112
34 Rate Schedule 131
35 Rate schedule 132
35 customer 1
37 customer 2
38 customer 3
39 Customer 4
40 Customer 541 Total Chanee 77.133.445
42
43 Rate Schedule 146 & Special Contracts 0
44
45 Total
45 % Change from Current Billed Revenue
S (10,372)
Prooosed Rates Total Billed % Chanse
Rate schedule 101 3,363,732 5 49,4o,8,740 5.
Rate schedute 111 1,496,803 s 15,176,000 9.
Rate schedule 112 0
Rate sch€dule 131 0
Rateschedule 132 L7,397 5 209,000 8.
Tab: Revenue Change Summary Pagei ! ot 17
Avista utilltles
State of ldaho
Summary of Changes
1
2
3
4
5
6
7
8
9
10
77
t2
13
t4
15
16
L7
18
19
20
2L
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
N
4t
42
43
44
45
46
47
rt8
49
50
51
52
Present
WACOG before revenue sensitive
Rate Schedule 101
Rate Schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
Proposed
WACOG before revenue sensitive
Rate Schedule 101
Rate schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
Change
WACOG before revenue sensitive
Rate Schedule 101
Rate schedule 111
Rate Schedule 112
Rate Schedule 131
Rate Schedule 132
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
s0.10289 s0.33162
s0.10289 s0.33162
s0.10289 s0.33162
s0.33162
s0.33162
so.to744 s0.37164
s0.7o744 s0.37164
s0.10744 s0.37164
S0.37164
S0.37164
.i
so.oo4ss So.o40o2
so.oo4ss s0.04002
so.oo4ss s0.04002
s0.04002
s0.04002
s0.43451
s0.434s1
s0.434s1
s0.33162
s0.33162
s0.47908
s0.47908
s0.47908
s0.37164
S0.37164
So.o44s7
s0.04457
S0.04457
S0.0,t002
s0.04002
Firm Sales Total Gas Cost
(Demand) (Commodity) Rate
GRF:
s0.10327
s0.10327
s0.10327
GRF:
s0.10798
s0.10798
s0.10798
s0.00471
s0.00471
s0.00471
1.003718
S0.33284
s0.33284
s0.33284
s0.3328s
s0.3328s
1.005016
s0.373s0
So.373so
s0.373s0
s0.373s0
s0.373s0
l::
S0.0'm66
s0.04066
S0.0,!066
s0.04066
s0.04056
s0.43611
s0.43611
S0.43611
S0.3328s
s0.3328s
s0.48148
s0.48148
s0.48148
s0.373s0
s0.373s0
:
s0.04s37
s0.04s37
s0.04s37
s0.04066
s0.04065
Present
ilACOG before revenue sensitive
tate Schedule 101
late Schedule 111
tate schedule 112
late Schedule 131
late schedule 132
Proposed
A/ACOG before revenue sensitive
late schedule 101
late schedule 111
late schedule 112
late Schedule 131
late Schedule 132
Change
I/ACOG before revenue sensitive
tate schedule 101
late schedule 111
late schedule 112
late Schedule 131
late Schedule 132
(Demand) (Commodity)
Amort Amort Total Amort Rate
(s0.00122) (s0.015s6) (s0.01778)
(s0.00122) (s0.016s6) (s0.017781
(s0.016s7) (s0.016s7)
s0.010s2
s0.010s2
s0.01174 so.oo619
s0.01174 s0.00619
s0.00619
(so.o1o37) so.oools(so.o1o37) so.oools
(so.o1o37) so.oools
s0.01793
s0.01793
s0.01793
(Demand) (Commodity)
Amort Amort Total Amort
1.003718
(s0.00122) (s0.01662) (so.o178s
(so.oo122) (s0.01662) (so.o178s
(s0.01663) (s0.01663
GRF: 1.005016
s0.010s7 (s0.01042) s0.0001s
so.o1os7 (so.o1o42) so.oools
(s0.010421 (s0.01042
s0.01179
s0.01179
s0.00620
s0.00620
So.oo621
s0.01800
s0.01800
s0.00621
CheckTotal: 0.06337
0.06337
0.04537
0.04587
0.04,066
Tab: Rate Change Summary Page2ol L7
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Avista Utilities
State of ldaho
Demand Cost Calculation (per Therm)
Line
No.Description Estimated Demand Expense
L
2
3
4
5
6
7
8
9
10
11
L2
13
L4
15
16
L7
18
19
20
2t
22
23
(A)
Northwest Pipeline Corporation (NWP)
TCPL - Gas Transmission Northwest
Total Fixed Domestic Transportation Costs
TransCanada - NOVA System
TransCanada - Foothills Pipe Line Ltd.
Spectra - Westcoast Energy lnc
Total Fixed Canadian Transportation Costs
Total Demand Costs
Demand Volumes (Th)
Demand Rate
4,601,836
974,471
5,576,307
1,914,560
907,535
491,322
3,313,617
924
82,744,540
0.L0744
1.005016
Demand Rate without RCF
Demand Rate with RCF
o.L07M
0.10798
Tab: Demand Page: 8 of 17
i-{
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Line
No.
AVISTA UTILITIES
Revenue Conversion F'actor
Idaho - Natural Gas System
TWELVE MONTHS ENDED JUNE 3O,2OI2
Description Factor
Revenues
Expenses:
Uncollectibles
Commission Fees
Idaho State Income Tax
Total Expenses
Net Operating Income Before FIT
Federal Income T ax @ 35o/o
REVENUE CONVERSION FACTOR
REVENUE GROSS UP:
I
2
3
4
5
6
7
8
L000000
0.0026s 1
0.002340
NA
0.99s009
0.348253
0.64676
(Ur-.004991)
Prior RCF
1.005016
I .0037 18
Tab: RCF (Conversion Factor)
Page: L0of L7
Avista Utilities
State of ldaho
Voluntary GRI Funding
Previous Pipeline Rate (Per Therm)
Current Pipeline Rate (Per Therm)
Reduction in Pipeline Funding Rate (Per Therm)
Montly Rate (Daily Rate x 365 Daysll2 Months)
NWP Demand Billing Determinates
Estimated Transportation Volumes (Therms)
GRI Funding Shortfall
ldaho Percentage
Total ldaho GRI Funding Shortfall
Northwest Pipeline
TF-1 TF.l
Reservation Volumetric
s0.00086 s0.00088
s0.00076 s0.0007s
Transcanada - GTN Pipeline Total
TF-1 TF.1
Reservation Volumetric
s0.00085 s0.00088
s0.00075 s0.0007s
so.oooro s0.00013
s0.00316
558,085,000
s0.00010 s0.00013
s0.00315
0
s1,764000
30.oLYo
So
3057%
SoSo
30.oL% 30.57%
S14,ooo s3,000 s9,000 ss,ooo s32.000
Set the GR! Funding at the 11/U99 tevet.
Tab: GRI Page:11of17
Foothllls Plpe Llnes Ltd.Prgc I
T.ITBLE OT EF]FECTTVE RATES
1. Retc Sehcdule FT, Flrm Trrnsportrtlon Servlce
Zane6
ZucT
Zmc 8t
Zcmc9
2. Rete Schcdule OT, Ovcrun Trrnsportrtl,on Serrlce
Dcrtrsnd Retc
($rGJ,,1ltur'Month)
o.0072t62549
0.0068502712
0.0l3s26o5iQ
0.004755367N\
Commodity Ratc
($loJ,/Km)
0.0002602584
0.0002470590
CoomodityRatc
($/cJ/Ko)
0.0004878249
0.000r715050
Zone 8 .0135260538 * t7O.7
= Total Rate 2.30890
Zonc 6
ZoteT
3. Rrte Schcdufc IT, Ilterrupdble Trelrportedon Scrvlce
Zonc 8+
Zcnre9
t For Zme 8. Shippcrs Haul Distaace shell bc 170.7 km.
TARIFF-PIIASE I Eftctirrc Ilo: Jaory 1, 2013
Tab: Pipeline Rates Page: L2of L7
NGTL Systmr
() r":r":s?"I*1d"
NGTL Syrtom
T'ansGanada's - NGTL SysEm TransportaCon Fldes
2013 lnt rlm R.De Eflle€uvr Jrnuery 1, 20lt
Rrcrlpt Sorvlc:r
ti[:BArE:agD Drmilrd Rate (3 yr tcrnfl i
lT.E (lnlerruFt b.l R€criFt)
OdhraryE rtlcG
Gmtrp 1:
EmFotrrl{cl{dill Eordc,
Ab.r€€.C- Sorder
Gcrfilndalc 8orerrEloundEry l-k tsordEr
A I (:O: dla rm'rntl$hell CrsalcFdaon
Ororp2:
FTCO No,th rSD poinls
FTCO Soulh t'ltf Firts
Albert MortsnelUni$ICold Lalre
All o,lhcr (!imr 2deiycty lEcnlld.rG
G.orp3:
lllTCO Nonh FSU Foinlc:
ATCO South F,sJ pcinB
All otEr Oroup $ OchrBry lo€lioni
T.rilf R.tE lnioanrdon Put;lorlt
Page I ulS
drillcf/d dilHBt.rd
(cdrl (ll3l
18.3 11.6
21.1 21 .S
T.rtlt ttm lniornrrtlon Purporcr
lrGJ tJoJrd fJmcFd fJililBturd
lcdn) (Cdnl tldtl tug!
5zgfino 17..t
${lrmE drgJ.rd
lcdnl (trdnl
18?.27tno 17.2
?.fi/d 't0:?
5-3
J-Iillno
3.tz/lno Alberta - BC
Border 5.38 *.90
(discount for 5+
years) = s4.8421.39/mo
!.12ho
].ggflilo
l.l Elftro
4.lUrno
3.7*/mo
l.Z4lma
r t.t
r0g
r00
rc.3
r3.5
123
12.e
It.r
.l9.'l
I I.S
tt.G
r 1.3
1J.3
tg5
t&s
t 1. r
r4.s
r 3.2
13.2
filer.C:ilETempiTc,rngrrnrry' Intsrnct FilcarContr,nt.Outft:okl.YXDA4lFUt\GT L Syrtem ... tl7-7?-ZUl 3
177
tu.u
3
Tab: Pipeline Rates Page: 13 of 17
Gas Transmissbn Northrrest LLC
FERC Gas Teriff
Fotuth Redscd l'oluos No. l-A
BASE
STF (e)
Iswed: Janury 11. .lol2
Effesth'er Janury l. 2Ol2
PART4
4.1 - statemtrt ofRates
fTS-f aod LFS-I Rates
r'.7.0.0 Sqcrseding v.6 O O
ST-{TEIUENT OF EFFECTI\,-E RATES A}ID CIIARGES FOR
TRAI.ISPORTAIION OF NATURAL GAS
Rate Schedrhs FTS-I atrd LFS-I
RESERVATION
DALY DAILYMILEAGE(a) NOI{-MILEAGE(b) DELI\IERY(c) FIJEL(O(D,th-[,fi,E) (D6) (DtL.Ivm,E) (DIh-MILE)
Ms:L Mir- Mar Mir MerL MiL Mfi- Mi!-
0.000498 O.00000O 0.039216 0.000000 0000016 0.000016 0.00500/c 0.00fi)7c
(e) 0.00O00O (e) 0.000000 0.000016 0.000016 0.005O7c 0.0000%
E]CTENSP}I CTIARGES
MEDFORD
E-1(0 0.003290 OOO@0O O.O05498 O.O0@0O
E-2 (tXD 0.009363 o.oooo0o
cwwP)
E-2 OXI) 0.002964 0.0oo0oo
@irmond r)
E-2(hxli o.mr!63 oo(rcooo
@iemond2)
COYOTE SPRINGS
OVERRIJ-\I CIIARGE (i)
SURCHARGES
ACA(td
E3(0 0_00141? o.o(nooo 0.001420 0.000000 0.o0000o 0.000000
0000026 0.000026
o.o00000 0.000000
0.000000 0.000000
ofixxmo o-fixmoo
o.oolS(N) 0.001800
fbcket No. RPr ^:-3Or 40O
Accepted: February 7. 20 12
Tab: Pipeline Rates Page: 14 of 17
Clas Traosmission Nuthrest LII
FERC Gs TTiff
Fourth Rcr/ised Voltmc No. 1'A
PART4.2
42 - Statcmol ofRatesffs-l Ritcs
v,3.o.O SryerscAhg v2.o.0
STATEMENT OT EFFECTITfERATES AI{D CIIARGES FOR
TRAI$SFORTATION OF \-ATURAL GAS (a)
Ratc schcdrlelTS-l
BASE
MILEAGJE(n)
(DbMte)
M!r- MiL
(e) O.O000O
NON{vflLEAcE (o) DEIJ\IERY(c) FUEL (O(Dh) (DtuMilc) (D6.Mi[e)
Mer- MiD- MoL Min- Mu- Mir-
(e) O-00000O 0.00@16 0.0q)0r6 O.O05O% 0-0o0o%
E'ilENSION CIIARGES
MEDFORD
E-l (-\,f!dford) (O
0.003290 o.oo@oo
COYO,rE SPRINGS
E-3 (Coyote sFirgs)(i)
0-001412 O.O0,0O0O
SURCEARGES
ACA(t)
0-@5498 o-qxD(x)o.omo?6 0.moo26
0_d)r420 o.oourco o-oooooo o.fiDo(xt
0.@18m o.ool8fi)
Issed: Augtrst 26. 20ll
Eftctive: octobcr l. 2ot I
Elocket IrIo. RP I l -2427{OO
Ascepted: Septeder 9. mll
Tab: Pipeline Rates Page: 15 of 17
Page E-4
!oLL S(HEITULLS - StRV|CL
APPENT}IXA
DETA}IO AIID COTTOIIITY TOLLS
TRAilSPffiTAIOI,I SCRVICE - SOUTHERN
Flm Trasportalioo Service - Sottlfiem
Decrand Tolsgnotnstm.
SenrceTgnt
l yBr
zlEals
3 tmrs
4 ycss
5 ycanorrnm
Ft{Ct ldildDcfruvftirt tlclrcrvrtea
Itl 91 3fi3fi7
l3/./8 :t53.t[
til1.65 3,,z.ts
13,227 338.S5
tI).09 335.{2
Flrrlirgdon
ttr{iuGrArla'
tr F?1
60r.9/
189.7,1
583.66
5n-50
Tcracnlfigsildcbltr{ilqdoo-
?ffiffi
254_ltr
I,l7-25
21/,.tO
142.15
' To lE iurpeqlrl kr ftn mrmrfan annrt rflhe tyfi*rh Hl
Fnhancnd T-qflrh SeJice
* FoFirmlransportsfist Seryb - Sumrern plouthd byWestmd&Ed Aptil 15, 2m2 betffi Westrod rd T€rffii GG lrr.
PhE orc arnanrl of tan or frrl gns cmsumd
(Brilhh Colurdia) rd te Cafton Ts Act
Wcstoat frraadr day httc mcnlft.
AOS and ht€rn[dile Tnmsportdon Sorvice -Southem
ComnrxlitrTdcsfl0#
f&rr, Huiligilrrlt/bnms IEIIgy tuirt IEtrwAEa t elE yAl€e ]tntnffi'
i,lorrnberb Iffir 6-t7t t5.812 27.8f It-,fl5
AFilbOcbbel1.648 11-859 z'J,.A 8.561
' Fer AO$ truuidGd by Wcstod pusurtb a Frm grui- irgrccmcnt daEd Aprfl f q 2fiE EuesrWcCmd ad Teran OG lnc-
PIE tte amqrt d ]rr. ol lueN m sptmed rt operilfrts pryabb m(hr t'e i,loffi l-rd !a Act
Gdbh Coturtaa) md te Cebon Ta Ad (Bilidr ,hrrttn) ttrifi b *cabd b $*,per by
Weeho*il formch day htte rnontt.
in a Seilhc Agrerrnnil fr
aFlrm ServiceAgeE rEnt
Frrl Ts ActSlipf.r by
Tqav:nXt{sl*k
Huntington Delivery Area, 5
years or more
Tab: Pipeline Rates
Etuivc lldc:Jrly 1,2013
Page: 16 of 17
NenfrratP[rlmGI
IERC C'rrTuififfiRa*rdl'ohnNo I ForfrRrriri SltctNo 5Sqcr*tft3
TlildRrryisdSlcrtNo. S
Rate Schedulc aad
Tlip'e of Satc
SIAIEUETIT OT RATESEffeccive Rates Applicable to
Rate Schedules TE-I, TF-z, TI-I, fEL-l(Dollarr per Dth)
BaseTariff RaceHiairrun Maxiraun ACA{2)
and fIL-L
CurrentlyEffesti\rcfariff Rate(3)Hiniuu lialdurn
Race Schectulc rF-I (4) {5)
Reservacion
(Large Custoner,Systeo-llide
15 Year Evergreen25 Year Evergreen
Volurnetric(targe Cultcrl
Systeu-Ilide
15 Year Evergrecn25 Iear Evetgrccn
(SraU Cuttorerl (6)
Scheduled Overrun
R.aEe Schedule TF-2 ({} (5)
ReservatioaVolunctric
Scheduled Daily OverruuAnnual Overlun
RaEe Schedulc rtr-lVolunetric (?!
ItaBe schedulc rEL-l (4) (5)
REservatLotrvoluD.tric
Schedulcd Overrua
Itarc Schedule TIL-IVoluDetric
.00000 . {1000Erp. .00000 .36263Exp. .00000 .3{23{
.00813 .03000E:A..000f3 .00813E:p. .00813 .0t E13
.0081s .72155
. t)0 ElS .44000
.00000 .{1000.00813 .03000.00813 .4{000.00813 .44000
.00813 .44000
- .00000 .41000
System-wide TF-1
.00180 .00993 .03180.00r80 .00993 .00993.00180 .00993 .00993 Volumetric
.03180
.00180
.00180
.00r80
.00993 . ?2335
. 00993 .44180
- .00000 .41000
- .00813 .0300000813 .4{00000813 .4,1000
. 00993 .44186
Tab: Pipeline Rates Page: L7 of L7
AVISTA UTILITIES
Case No. AVU-G-13-0]!
E)GIIBIT "D"
Pipeline Tariffs
July 30,2013
Northwest Piprlinc GP
FERC GasTarilt
Fifth Revised Yotrme No. I
Secqnd Revised Sheet No. 16
Superseding
First Revised Sheet No. 16
EATE SCI{EDIILE TF-1
Pirrn Transportat,ion
AvArr,ABrr.rrY
T,his R.aLe Schedr,rle is avail,able as provided herein and
ineorporates the General Tenms and Cond!.tsions to any party thereiuaftercalLed dshitrper") for Ehe transportation of natu:ral gas by Transporter
tbrough TransporLei's mainline t,ranemission system uuder the following
condl-tions:
(a) Shipper desires flrm service and Tfan,sporter }ras available
capacity to render such firm serl/ice for shipper. If at. Ehe tirne
aervice is reguested under bhis Late Schedule, Transporter doesnot have capaclty to recelve firm transportaE.ion gaa'at Lhereceipt poinE(s) reguested for redelivery at the de11verypcint (s) requesEed, Traneporter shall offer Eo receive firm
Lranspertatlon gas a[ obher receipt point (s] where eapaclty may
be available to enable redelivery af Lhe delivery poirt (s)
reguested;
(b) TrarsporEer can commence the service corEemplated wiEhouE
need for eonstrucLion oE dny addiLional pipeline fasilities,excert faeiliLies for ryhieh i Eacilities agteernent hae beeq
entered iabo betx,reen Transportser and Bhipper pursuant to Seceion
2x or 29 of the General Terms and Condit,ions of this Tariff,i. and
(e) Shipper and Tlianst)oiter bave exebuEed a gervice Agreemdntfor service under tttis Rate gaheduL,e.
As used in this Rate Seh.edule. rransporter's mainlinetranamission system does nots include Designated Later?.1s.
AFPI,ICABIIiT?Y AI{D CHLRACT&R oF SER\IT'CE
2.L applicability. This Rate $cheduLe shall apply to gas transported
by Transporter for Shipper pursuaRt to Lhe execuLed Service AgreemenLfor seivice under Ehis Raf,e Schedule for TF-1 (Large cueEomer) and lF-1"
tSrnall CusEomer) service. The Seryice AgreemenE will specify trhe
cirstamer caEegory, i.e., wheEher Lhe Shipper is a Large Customer o!-
Sma1l cuscomer and, lf the Shipper l-s an incremenual expaneion
cusLomerr whether i,he Shipper is. a Colnrnbia Gorge Eryansion cqetomer, a
ls-Year Evergreen Expansion cusLomer or a zs-Year Evergreen Expanslon
custofter.
Exhibit D - Pipeline Tariffs Page 1 of55
,
Northwest Pipeliue GP
FERC Gas Trriff
Fifth Rcvised Volume No. I
Firs( Revised Sheet No. l?
Superseding
Substitute Original Shect No. l7
RATE SCX{EDUI,E TF-1
Firm TrarrsportsaLlou
(Corrtinued)
APPLICABILIEY AND CHARACTER oF 9EEVICE (ConLinued)
(a) Tf-l (Large cu,sto$er): .&11 rate pr.ovigions contained ln
tbis Eafe Schedule appty tso TF-1 (Large Custome::s) -
(b) TF-l (smal1 CusLomdr): A TF-1 (small CusLomer) is anypipeline or diBEribution company which elects Rate schedu.le TF-1
(Sma1l C,usEomer) servic€ end whoee aggregatse Contract Demand, as
specified in ius service AgreemenE.(s) hereunder, ts for I0,000
Dnh per day or lese. {A Shipper qualified to elect, either the
TF-1 (Srnal1 eusEome.r) or TF-l (Large CuBt.omer) service hereunder
may change lts election permanently only in conneccion with uhefiling of a grenetal SeeEion 4 rate case by Transportrer.
Transporcer shall provide sueh shippers with en oppqrtuni.ty tcr
ma,ke such ql elecEion prior Eo filing such rate applicati.ons.)
(c) Capaeity Release Serrrice is service iniciated pursuant Eo
Section 22 af Ehe Genetal Terms and CondlLions and ari execuLed
Service Agreemenl for Ratse Schedule 11F-1 (Large Customer)
senriae.
(d) Any Rate Schedule TF-1 (Small Customer) shipper may conver!all of its senrice Lemporarily Lo TF-1 (Large customer) service
to participate, in Transporter's Capaeity Release Progranr without
arnending its service agreerrtent, provided thaL Euch Len5>ofary
conversion shall be for a minimum cenn of Ewelve calendar months.
Notlce of bhe inUenb Eo sg qoRwert Eempora:ri1y ro Ir-1 (Large
Customer) service musE be given E.o Transporuer eleetronically
uslng the TF-I (Small custamerl Lemporary conversion election
scredn available in NorEhweat gassage on Transporter's Designdted
SiEe at Leasb one (1) week prlor to the beginning oonLh for which
euch conversLon ls to bqcome effect,lve. Shipper's Eernporary
qoaverslon elecElon collgEiEut-es agreement Lo the t.emporary
converslorl" Any TF-1 (Sma1l customer) Shiprper parEiclpatlng in a
tenpotary conversion to fF-1 (Large Cusf,omer) service shal1 pay
all. rabeg artd charqea appllcable to TF-1. (Liirge customer) service
Exhibit D - Pipeline Tariffs Page 2 of 55
Northwgst Pipelinc GP
FERC Ger Tariff
Fifttr Revised Yolume No. t
First Revised Shaet No" l7-A
Superseding
Substitute Original Sheet No. l7A
2.
RATE SCEEDULE TF-I
Firm TrangporEaE,ion(continued)
APPLIeASILIry AND CH.&RACTER OF SERVICE (Cont.inued)
2.1 (d) (Contlnued)
during the teru of eueh temparary convereion, includi.ngresenation charges and surcharges appllcabla to such shipper'sfull eonLracL demand ot such oEher rate Ep vhich TralaporE,er 4ndShipper mutually a€Jree, reiduced as appLicable by revenue creditsapplicalle to Released Capacity. Any Rabe Schedule TF-l (SmalL
CusLoner) Shipper which part.icipaEes ln such a temporary
convergLort ehall be entiLled lo returr Lo Rate Sqhedule TF-1
(.S$a11 Custonet) serviee upon ercpira.iion of the Ler-m of ttre
teworary corversion regueEEed by sueh shlp.per. .Hol,rever, such
Ehipper sball nou be ea-E,itLed tg releaqe'itg capaqiuy right,s fora ter& r*hich extends beyond the f,erm of lhe Lemporafts conversion"
2.2 f,ransportatloa Compangnes. Transportation service u::der t,his Ra.te
Schedtl"e, which does not iqclude service oa Deeignated Laterals, sha11
eongist of:
(a) The receipt by fran8porLer for t,he accounE. of shipper of
Shipper's gas aE the Receipt Point(e) spacified in the executed
Servlce Agreement;
(b) The cransporEatio[ of such gas through Tran.spo].tetrrspipeline syat,em for the aqcorme of Shipper elther directly or by
displacement; and
Exhibit D - Pipeline Tariffs Page 3 of 55
Northwe$t PiplineGP
FERC Gas Tariff
Fifth Rcvised Volumc irlo. I
Fint Rerised Sheet No. lE
Superseding
Substitute Originrl Sheet No. 16
2.
R.ATE SCHMUIJE TF-I
E irm TransporEatslon (Continued)
APPTICABTTITY AND CHARACTER OF SER,1rJCE (CONtiNUEd)
{c) Tbe delivery of gas in thermally eguivalent guanEiEies
afLer transporLaEion (lesg any fu.e1 use reimbursemenE furnisbedin-kind in accordance w:ith Section 14 of the General Terrns and
Condirions) by Transporter to Shipper or for the account of
Shipper aL the Delivery point (s) specif ied in the e:r.€cutedgerviee AgfeemenL.
2.3 CharacEer of Serniee. Tra[sporEation Ber\rice rendered Eo ShipBer
under this Rate ScheduLe is firm up to Shippert s ConLract Demand asspecified in its executed Service Agreement, subjecc to the executeci
Service Agreement and Lbe liriitations of this Eate Sehedule, and is not
subJect, Lo curEailmenh or internrption except as expressly provided i.nthe Cleneral Terms and Corrdit,iong" Trarsporbation ser\,ricq rendered underthis Ratre Schedule in excess of Shipper's Cont,racE Demarrd is not firm.
MONfl{LY RATS (S}
Each. month. Shipper will pay Transporter for servLce rendered
under thie Raue Scbedute Lhe eurn of the anauats specified in thls
seqtton 1. as applicable- only those rate. provisions contained in
Secelons ?,2, 3.4, f,.F af.ld 3,7 appl.y to f8*1 (Ernal1 CusLomers) .
3.1 Reservation gharge.
(a) For TF-r (IJafge cus'Eonerl servicq, th€ Rese:ivation chargeis the sum of the daily pr.oducc of shipper's Tranapartat.ion
eoncracu Demand as speclfied in the executed service Agreethent
and the'BaEe Tariff ReservaEion Charge stsated on Shedt No. 5 ofrhls tariff uhau appltes to the eusEomer category ideqtLfied in
the Service Agreem€nt. Ualess specifically adjusted pursuant to
Section 3.5 hereln. Lhe Maximum BaEe'Iariff Rate set forLh on
Sheef, N<:. 5 will apply.
For capaelti re}ease service. Ehe Reservation Charge ls rhe
eum of the daily product of Ehe accepte{ reeerqation charge bid
3.
Exhibit D - Pipeline Tariffs Page 4 of 55
Northwcst Pipeline GP
FERC 6as TsrifT
Fiftb Revised Volume No. I
First Revised Shcct No. l&A
Superseding
Substifute Originel Sheet No. 1&A
3.
RATE SCIIEDIJI,E TF-1
Firm Transportation(Continued)
Molq[l{IrY B.PffE (S] (CoaLinued)
price which eras bid by a BeplacemeRE shipper or a Ptearranged,
REBlacefient, Strlpper under Lhe btdding procedrrres for capacityreleases set, forth in Section zz ol tbe General Terme and
Conditions and the conEract denand acgu.ired by Lhe Replacement
Shipper or the Pl:earranged Replacemene Shipper.
(b) $hipper will pay the Reaervation Charges commencing r+iLh the
primary Eerm begin dat.e set fort.b in the Serylce AgreemeoL.
3.2 VoLumetric Charge: 71re sum of (a) and (b) below:
(a) An amount obtaioed by rmrlEiplytng (i) Lhe quantiEy of DEh
scheduled for dellvery by Transporger to shipper after
transporEatlon durlng the,montsh, afEe:: reduation for f,uel use
reinbureement fLr,rnished In kind in accordance with the terftis ofthe exesuted Eervice AEreements ar|d section 14 of the Ger:eral
Terrns and Conditions, by (j,1) the TF,-l (Large Customer) or fF-L
(sma1I CusEomer) Base Tariff Volumeurlc TraneporEat.ion rat.e asset forth on gheeE No. 5 of this ?arlff. Unless specificallyadjusted pursuanu bo gectiop 3.5 herein, Lhe Maxiunrm Base Tariff
Rate set forth on Sheet No. 5 shall apply.
(b, An amoune obtained by multiplying (i) Ehe guantity of Dth
sclredul.ed for delivery by Transporeer Eo Shipper after
LransporLation dur,lng the monEh, after reducLion for fuel use
rqirnbureemert furnished in kind ia accoritance wit,h Ehe terms oflhe executed Servlce Agireement and Seclion 14 of Ehe general
Ternts and eonditions, by (ii) the Atle comppflenE aa seE forth ongheeE No. 5 of thj,e T4r{ff,. This oharge shall be subJecr Eo
adjustmen't in accordance r+lth section 16 of the General Terms ard
Condlt'ions.
3.3 Volumetric Release Charges: For CapaciLy ReJ.ease service pursua[t
to SecElon 22 of the General TerraS and. Condltlons rshich i,s provided
und.er a volwnetric bid rate th€ eun of {a) , (b) and. if applicable, (c)
beLow:
(a) the amount obLained by rmrltiplying (t) the guant.ity of Dth
scheduLed for delivery by TransporEer Co R€p1ac€ment Shipper orprearauged Replacement ShiBp€r afcer tra$sportaEion durlng ttre
monLhr after
Exhibit D - Pipeline Tariffs Page 5 of 55
Northwest Fipelinc GP
FERC G*s Tsriff
Fifth Revised I'olume No. t
Sccond Revised Sheet No. l9
Supersediag
First Revised Sheet No. l9
3.
RATE SCI{EDITI,E TF-I
Firm Transport,aEion
(ConEinued)
MONTHTY RATE(S) (ConEinued)
reduction for fuel use reldbureemen! furniElred tn kind in
aqcordance with t,he Eerrlrs of the executed Service Agreenene and
seet,ion 14 of Ehe General Terms and Conditions, by (i1) rhe
accepted volumeErlc bid made by a Replacement Shipper or a
Pfearanged Repl3ceqent, Shipper and by (iil) t.he RaE.e SchedulefF-l Capeeity neleqse gerllce Base Tariff tolumeEric Charge. boeh
a6 set forLh ort Sheel No. 5 of Lhis Tariff.
(b,The amormL set forth lrt Seet,ion 3,.2 (b) hereof .
(c) If the Retreasing Shipper has specified a mlnirnum average
Load factor volumeLric commi,tment, an anowrt egual to the acceBted
volumeEric bid times the dif fere.:ace. if positJ"ve, between (i) the
specified average load factor Limes Replacement Shipper's or
Prearranged Replacement Shipper' s Transportatiorr Con.tract Demand
Limes Lhe number of days tbe Transportation Service Agreemeng isin effect durlng the month, and (il) the guaDtity of DE.h deLivered
by Transporter to Replacement Shipper or PreasraDged Replacedent
Shig4rer under Lhe Eubject, .service Jtgreemenb during ehe month.
3.4 Additional }'aciliEy Beservation gurcharge: a Shlpper w'ho
conEraqta for Columb,la Gorge Expansicln Project. capaeitlr wl}1 pay thefacilitir festslviition sr.rrchqr$g set fgfth in che footnotes to Sheet No. 5of thid Tariff and such surcharge w111 be in addltioa to all other
applicable raceE sEated in this Sectiot 3. The facllity reservation
surcharge r.ras derived based on TransporLael"on conEract. Demand and uhe
cosf, of serylde aEtrrlbutable co the Colunbia Gorge Fi:(pansio4 ProJeet
inoremental facilitiea and suoh derivacioD wiLl" tematn ln place until
sueh Eime as a differenE allocaE,ion procedure ls specified by Conmisslonorder. The mont.hly faclliLies reservation surcharge wi).l be Ehe sum ofthe dally produet of Shipper'a Transportation Contrract Demand asspecifled in t.he execueed Service Agreement and the applisable facilityreservatj.on surcharge for uhe Columbia Gorge Expansion Projecl:facilieies specified in the FootnoE€s t,o Sheet No, 5 of chis Ta.riff .
Exhibit D - Pipeline Tariffs Page 6 of 55
Northwest Pipelioe GP
FERC Gas Tariff First [evised Sheet No. l9-A
SuperscdingFifth Revised Yolume No' I
substit'te originat she€t No. lg-A
RATE SCHEDUIJE Tf-l
Firm Transportatsion
(Contsinued)
3, M0NTHLY RAtE(S) (ConLinued)
3.5 DiscoimEed Recourse Rates:
{a) TrausporLer reserves the righe to d.lscounE" aE any Llme Ehe
Recourse RaLes for any lndividual shlpper u.nder any servlce
ag,reemenL r*ithout discounciug afly oCher Recourse Rates for Ehat or
anoLher $hipper; provided, houever, Ehat such dj.scounted Recourse
RaEes will not be less Ehan the Minimum Currently Effective BaEesset forLh on Sheeu No. 5 of this Tariff, or any supersedtrng
Earif f . Such d.iscount,ed Recourse P.ates may apply io specitic
volumeB of gas (such ag volumes above or below a eertaln leveL orall volumes if volumes exceed a certain leveL), volumes of gas
Uransporierl during specific ti-me periode, and volumes of gas
Eranapoited from speciflc receipE points and/or Eo specific
del.ivery poioEs, within specilio corridors, or wiehj.n other
defihed geographlcal argaB. If frahsporter discounts arry Recourse
RaEes 9() a:ly Shipper, Transporter will tile wiuh the Cofimission
any reqpi.red r€Forts reflecting such dletroutrts.
Exhibit D - Pipeline Tarifis Page 7 of 55
Northwcst Pipeline GP
FERC Gas Tariff
Fifth Revised \,olume No. I
Second Revised Shect No.20
Superseding
F'ir:st Revised Shcet No.20
3.
RATE SCH.EDUIJE TF-1
Flrm TransF,ortaE.ion
(Continued")
MONTHLY RATE(S) (Continued)
3.6 ehargas f.or Capacity Releasq Service: the rat.es for capacicy
release service are set, forgh in Sheet No. 5. See gectsion 22 cf Lhe
General Terrns and CondiLions for lnformation abouc raees for capacity
releaee service, including informatlon about acceptable bi.ds" In Ehe
evenE of, a base Lariff maxl-mum andlor mlnimrm rate chaage, rrrherein Elre
RepLacemenu shipFer has noE agreed to pay Lhe max.imum base Eariff rateor a percentage of the maximrn base tariff rate (ag ic may change f,rom
f,ime-to-t.i.me), the Replacenent $hipper will he obligaled Lo pay:
(a) for capacity releaee Erans:actions that are suhjeeE to the
maxinum bas,e larlff rate pursuant. co FERC reg:ulaEions: the lessero( tlie awarded. bld ratse and the nerr m4xirnum base tarif,f raue
ua'less Lhe awarded bid sate is lees Ehan tshe new minimum raLe, in
which case the new minimum laLe will apply for tshe remainlng termof t.he release
(b) for eapaciLy release transactions that are rot subject Eo
t.he maxi*lum base tariff rate purisuantr to FERC regulauions: Lhegreater of the minimurn hase Larlff rate and the awarded bld rate
for the remairr-ing t€rm of the release.
3.? Negotiated RaEes: NotwiLhstandlng the generaL provisions of this
saceion 3, lf Transportser and shipper mutually agree to Negouiaced
Rates fer Eervice hereunder, sueh Negotiated. Rates wil-1 apply in lieu
of Ehe other$ise applicable raEes ldenrified in Lhis seciion 3.
3.9 Facilities charger If TransporEer and Sh.ipper enEer into af,acilibieg agreemen! pursuanE. to gectiion 2L or 29 Af Lhe Geheral Terms
and CondiEions fo::'Tranaporter to con3Eruau facilistres and for Shipper
Lo pay a facillEi,es chaige, Che faeilities charge will be set Eorth on
Exhibits C to an executed Service AgreemenL.
Exhibit D - Pipeline Tariffs Page I of 55
Northwest Pipcllac GP
FERC Gas Tsriff
Fifth Revised Yotume No. I
First Revired Sheet No.2&A
Superceding
Substitute Originel Sheet No.20-A
4.
RATE SCI{EDUIJE TF.l
Firm TrarrsportaEion
(Contsinued)
MINT}IUM MONTHLY BII,L
unless Transparten and Ship1)er mutrrally agree otherwise, Lhe Minimuq
MOnthIy ail] rrill cousist o$ tshe Reservat,ion Charge specified in
Section 3.1 of, this Rate Schedule. as applicable-
TRA}iISPORTATIO}I CONTBACT DEMAI{Ti
The EransportaEion conEracE Demadd is the maxlmurn $hntity of cas,
er.pressed in Dt.h. LhaL Translroftser ie obligated to reqeive (exe].u,slve
of fuel rei.rrlursement Etrrnished ln-kind purauant Lo SeeLion 1.4 of trhe
ceneral Tetrms and conditiens), trarl€port aad deliver foi Shipper on a
Exhibit D - Pipeline Tariffs Page 9 of 55
Gas Transmission Northwest LLC PART 5
FERC Gas Tariff RA'IE SCI'IEDULES
Fourth Revised Volume No. I -A v.?.0.0 Superseding v.1.0.0
RATE SCHEDULES
Firm Transportation Service fTS- I )
Limited Fiifi Transportation Service (LFS-l)
lntemrptible Transpo*ation Service (ITS- I )
Unbundled Sales Service (USS-l)
Parking Service (PS-l)
Authorized Imbalance Servioe (AIS- I )
Issued: April I l, 201I
Effective; April4, 201 I
Dockot No. RP I l-198G000
Aooeptcd: May4,20l I
Exhibit D - Pipeline Tariffs Page10of55
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
lssued: April I1,201I
Effeetive: April4,20l I
PART 5.I
5.1 - Rate Schedules
Rate Schedule FTS-I - Fhm Tranqportation Ssrvice
v.2.0.0 Superseding v. I .0.0
RATE SCHEDULE FTS-I
FIRM TRANSPORTATION SERVICE
Dooket No. RPI t-198G000
Acccpted: May 4, 2011
Exhibit D - Pipeline Tariffs Page 11 of55
Gas Transmission Northwest LLC
FERC Gas'l'ariff
Fourth Revised VslumeNo. l-A
Issued: April I l, 201I
Effective: April4, 201 I
PART5.I.I
5.1 .l - Rate Sched I;1'S-l
Availability
v.2.0.0 Superseding v. I .0.0
5.I.I AVAILABILITY
'l'his rate schedule is available to any party (hereinafter called "Shipper") qualifying for
service pursuant to the Commission's Regulations contained in l8 CFR Part 284, and who
has executed a Firm Transportation Servioe Agreement with GTN in the form contained
in this FERC Gas Tariff, Fourth Revised Volume No. l -A.
Dockel No. RPI l-1986-000
Accepted: May zt, 2011
Exhlbit D - Pipeline Tariffs Page 12of55
Cas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I l,201I
Effective: April4, 201 I
5.I.2 APPLICAEILII'Y AND CHARACTER OF SERVICE
This rate schedule shall apply to firm gas transportation services performed by GTN lilr
Shipper pursuant to the executed Firm Transportation Service Agrecment betwcen GTN
and Shipper. GfN shall receive from $h{pper such daily quantities ol gas up to the
Shipper's Maximum Daily Quantity as specified in ths executed Firm Transporlrtion
Service Agreement between CTN and Shipper plus the required quantity of gas for fuel
and line loss associated with service under this Rate Schedule FTS-I and redeliver an
axnount equat to the quantity reoeived lsst tfte required quantity of gas for fuel and line
loss. This transportation service shalt tr firm and not zubject to cunailmont or
intem-rption exaept as provided irt the Transportation Gcneral Terms and Conditions. A
Shipper's Maximum Daily Quantity shall be a uniform quantity tlrroughout the contraet
terrn, except that GTN mayi ort a not unduly discriminatory basis, agree to differing
monthly levels in the Shipperls Maximum Daily Quanlity during thE term of Shipper's
contract. Shipper's Maximum Daily Quantity and any differing levels in the Maximum
Daily Quantity, as well as the period of such differing Maximum Daily Quantity lcvels.
shall be specified in the executsd Firm Transportation Sorvice Agreement.
Firm transportatiorr ssrvice sha.ll be subject to all provisions of the exeouted Firm
Tninsportation Serrrico Agreement betwesn GTN and Shipper and the applicable
Transportatton General Terms and Conditions.
PART 5.I.2
5.1 .2 - Rate Sched FT.S- |
Applicability and Character of Service
v.2.0.0 Superseding v. 1,0.0
Dockst No. RPI l-1986-000
Accepted: May 4, 201I
Exhibit D - Pipeline Tariffs Page 13of55
Gtts Transmission Northwest LLC
FERC Cas Tar,iff
Fourth Revised Volume No. l-A
Lssued: May 26, 201 I
Effective: June27,20l I
PART 5.I.3
5"1.3 - Rare Sched FTS-l
Rates
v.3.0.0 Superseding v.2.0.0
5.I.3 RATES
Shipper shall pay GTN each month the sum of the Reservation Charges, the Delivery
Chargq plus any applicable Extension Charge, Ovsrqn Charge and applicable surchargcs
for the quantities of natur*l gas dolivered. The rate(s) set forth in GTN's current Effective
Rates and Charges for Transportation of Natural Gas in this FERC Gas Tariff, Fourth
Revised Volume No. I-A are applied to transportation service rendered under this rafe
schedule.
Docket No. RPI l-2132-000
Accepted: June 10,201 I
Exhibit D - Pipeline Tariffs Page 14of55
Gas Transmissisn Northwest LLC
FERC Cas Tariff
Fourth Revised Volume No. I-A
Issued: May 26, 201 I
Effective: June27,20l I
PART 5.1.3.1
5.1.3.1- Rate Schsd f'TS-l
Reservation Charge
v.3.0,0 $uperseding v.2.0.0
5.1.3.1 Reservation Charge.
'l-he Reservation Chargc shall be the sum of the Mileage and the Non-Mileage
Component:
(a) Mileage Component.
The Mileage Component shall be the product of the currently effective
Mileage Rate as set forth in Seotion 4.1, the distance, in pipeline miles,
from the Primary Poiflt(s) of receipt t0 thc Primary Point(s) of Dclivery on
Mainline Fapilities rrs set fortlr in Shipper's Conract, and the Shipper's
Maximum Daily Quantity at sueh Poin(s).
(b) Non-Mileage Component.
The Non-Mileage Component shall be the product of the currently
eflective Non-Mileage Rate ss set fomh in Section 4.1 and the Shippcr's
Maxirnum Daily Quantity at Primary Foint(s) of Delivery on Mainline
Facilities.
(c) Shipper's obtigation to pay the Reservation Charge is independent of
Shipper's ability to obtain export authorizatisn from the National Energy
Board of Canbda, Canadian provincial removal aulhority, andlor import
authorization frqm the United States Department of Energy, and shall
begin with the execution of the Firm Transportation Servicc Agreement by
both partios. The Reservation Charge due and payable shall be computed
beginning in the month in which service is first availablc (prorated if
beginning in the month in which serviee is available on a datc other than
thc ftrst day of the month). Thereafter, the daily Rcsorvation Charge shall
be due and payablc each month during the Initial (and Sub.sequent) Terrn(s)
of the Shipper's executcd Firm Transportstion Service Agtcment and is
ufiaff'scted by the quailtity'ofgas transpofied by GTN to Shipper's delivery
point(s) in any month exsept as pmvidcd for in Sections 5.1.3.9 and
5.1 .3.10 af this rate schealule.
.Dooket No. RPI I-2132-000
Accepted: June 10, ?01 I
Exhibit D - Pipeline Tarifis Page 15 of55
Gas Trsnsmission Northwest LLC
PERC CasTariff
Fourth Revised Volunre No. I-A
Issued: April I I, 201 I
Effective: April 4, 201 I
PART 5.t.1.2
5.1.3.2- Rate Sched FTS-l
Delivery Clrarge
v.2.0.0 Superseding v, L0.0
5.1.3.2 Delivery Charge.
The Delivery Charge shall be the product of the Delivery Rate as set furth in
Sectbn 4.1, the quantities of gas delivered in the month (in Dth) (excluding
Authorized Ovemrn) at poin(s) of delivery on Mainline Facilities, and the
distance, in pipeline miles, from the point(s) of receipt to point(s) of delivery on
Mainline Facilhies.
Docket No. RPI l-1986.000
Acccpted: May4,20l I
Exhibil D - Pipeline Tariffs Page 16of55
Gas. Transm issioir N orthwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
Issued: April I l, 201I
Effective: April4,20l I
PART 5.I.3.3
5.1.3.3- Rate Sched f:TS-l
Extension Charge
v.2.0.0 Superseding v. 1 .0.0
5.1.3.3 Extension Charge.
If Shipper designates a Primary Poin( of delivery on an Extension Facility, then
in addition to all other charges that are applicable, Shipper shall pay the
E'xtension Charge, which shall consist ofa reservation and delivery component.
(a) The reservation component of the Extension Charge shall be the produet of
Shipper's Marcimum Driily Quantity at the Prirnary Point(s) of delivery on
the Extension Facilify, tho appticnble Enteasion rcsefvatioil rate as set fotth
in Seotion 4.1, and the distanoe, in pipeline miles, fiom the Receipt
Point(s) on the Extension Facility to the Primary Point(s) of delivery.
(b) The delivery compenaut of the Extension Surcharge shall be the Frodqct of
the quantities delivered at the point(s) of delivery on the Extension
Facility, the applicable Extension delivery rate as set ,brth in Section 4.1,
and the distance, in pipeline miles, from the Reccipt Point(s) on the
Extension F'acility to the point(s) of delivery.
DocketNo, RPI l-1986000
Accepted; May 4,201I
Exhibit D - Pipeline Tariffs Page 17 of55
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No, l-A
lssued: April I l, 2011
Effective: April 4, 201 I
PART 5.1.3.4
5.1.3.4- Rate Sched FTS-I
Authorized Ovemrn Charge
v.2.A :0 Superscding v. I .0.0
5.1.3.4 Authorized Overrun Charga.
Quantities in excess of Shipper's MDQ shall be transported when capacity is
available on the GTN system and when the provision of such Autlorized
Overruns shall not affect any Shipper"s rights on the CTN System. Authorized
Overuns are intemrptible in nature. The ratc charged shall be the same qs the
rates and charyes for intemrptible transportation under Rate Schedule ITS-I as
set {brth in Soction 4.1, and such Authorized Overruns shall be subject to the
priority of service provisions of Section 6.19 of the Transportation Ceneral
Terms and Condhions.
Dooket No. It.PI l-1986-000
Accepted: May 4, 2011
Exhibit D - Pipeline Tariffs Page 18 of 55
Gas Transmission Northwest LLC
FERC Cas Tariff
Fourth Revised VolumcNo. l-A
Issued: Aprit I l, 201 1
Effcctive: Apri[ 4. 201 I
PART 5,I.3.5
5.1.3.5- Rate Sched FTS-l
Appl icabi lhy of Surcharges
v.2.0;0 Superseding v. I .0.0
5.1.3.5 Applicahility ofSurcharges.
Shipper shall pay all rescrvation and usage surcharges applicable to the service
provided 0o such Shipper as set forth in CTN's FERC Gas Tariff, Fourth
Revised Volume No. t-A. Such surcharges shall be deemed to be part of
Shipper's REservation and Delivery Charges.
Docket No. RPt l-f 986-000
Aocepted: May 4, 201 I
Exhibit D - Pipeline Tariffs Page 't9 of 55
Cas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
IssuerJ: April I l, 201 I
Effective: April4, 201 I
PART 5.1.3.6
5.1.3.6- Rate Sched FfS-l
Discounts
v,2.Q.8 Superseding v. I .0.0
5.1.3.6 Disccrunts,
Shipper shall pay tfie Maximum Reservation Charge, and the Maximum
Delivery Charge for service under this Rate Schedule unlsss CTN offers to
discount the Mileage Rate cornponents or the Non-Mileage Rate components of
ths Reservation [t"ute or the Delivery Rate under this rate schedule. ff CTN
elEcts to discount any such rate, GTN shall" up to forty-eight (48) hours prior to
such diseount, by written netice, advise Shipper of the effective date of such
charges and the quantity of gas so affected; provided, however, such discount
shsll nor be anticompetitive or unduly disoriminatory bet*.een individual
shippers. The ratcs for scrvioc under this rate schedule shall not be discounted
belorv the Minimurir Reservation Charge, the Minirnum Delivery Rate, and
applicable ACA Surcharge.
Docket No, RPI l-1986-000
Accepted: May 4, 201I
Exhibit D - Pipeline Tariffs Page 20 of 55
Gas Trsnsmission Northwest LLC
FERC Cas Tariff
Fourth Revised Volume No. l-A
lssued: April tl,20l I
Effectivo: April4, ?01I
PART s.1.3.7
5.t.3.7- Rare Schetl FTS-l
Backhauls
v.2.0.0 $uperseding v. 1.0.0
5.1 .3-7 Backhauls.
Backhauls (as defined in Section 6.1 paragraph 3l of the Transportation Ceneral
Terms and Conditions) shall be subject to the same charges as fonvard haul (as
defined in Seation 6.1 paragraph 30 of the Transportation Ge neral Terms and
Conditions) except that no gas shall be rttained by GTN for compressor ststion
fuel, line loss and other unaccounted-for gas. Backhauls are subject to the
operating conditions of CTN's pipeline and. will not be made available to
Shipper if GTN dotermines, in its sole discretion, that such transportation is
operationally infeasible or otherwise not available.
Docket No. RPI l-1986-000
Accepted: May4,20ll
Exhibit D - Pipeline Tariffs Page 21 of55
Gas Transmission Northrvest LLC
F'ERC Gas Tariff
Fourth Revised Volurne No. I-A
Issued: April I l, 201 I
Effective: April 4, 201 I
5.1-3.8 Capacity Rclsase.
(a) Releastng Shippcrs:
Shipper shall have the option to release capacity pursuant to the provisions
of C'l'N's capacity release program as specified in the Transpoftation
General Terms and Conditions. Shipper may release its capacity, up to
Shipper's Maximum Daily Quantity under this rate schedule, in accordance
with the provisions of Section 6.28 of GTN's Transportation General
Terms and Conditions of this FERC Gas Tarifr, Fourth Revised Volume
No" l -A. Shipper shall pay a fee assoqiated with the marketing of capacity
by GTN (if upplicable) irt accordance with SEction 6.28 of the
Transponation GeneralTenns and Conditions. This fec shall bc negotiated
between GTN and the Releasing Shipper.
(b) Replacement Shippers:
Shipper may reeeivc released capacity service under t'his rate schedule
pursuant to Section 6.28 of the Transportation Gensral Terms and
Conditionq and is required to execute a service agreement in the form
contained for capacity rcle&se under Rate Schedule FTS-I in this Fourth
Revised Volume No. l-A.
Shipper shall pay CTN eaqh month for transport4tisn service under this
rate schedule and as set forth in GTN's current Statement of Effective
Rstes and Charges iri this Fourth Revised Volume N0. l-A. Charges to bo
paid shall be thc sum ef the Rese.rvation Charge* Delivery Charge, and
other applicable surcharges or penalties.
The rates paid by Shipper receiving copacity release mrr.spCIrtation service
shall be adjusted as provided on Exhibit R in the sxccuted Transportation
$ervice Agreement For Capacity Releasc betwetn CTN and Shippcr.
PART 5. t.3.8
5.1.3.8- Rate Schcd FTS- l
Capacity Re [ease
v.2.0.0 Superseding v. I .0.0
Docket No. RPI l-1986-000
Accepted: May 4, 201 I
Exhibit D - Pipeline Tariffs Page 22 ot 55
Gas I'ransmission Northwest LLC
FERC Cas l-ariff
Fourth Revised Volume No. l-A
Issued: December 6,2012
Effeotive: Jsnuary 12, 2012
PART 5.1.3.9
5.1.3.9- Rate Sched FTS-I
Reservation Charge Credit - Force Majeure Event
v.5. 1.0 Superseding v.3.0.0
Docket No. RPl2-15-005
Aocepted; Jonuary 16, 2013
5.1.3.9 R.eservation Chaige Crcdit - Force Majeure Event.
As used in this Section 5.1.3.9, Firm Daily Volume shall mean the volume of
gas which GTN is obligated to deliver on a firm basis al Shipper's primary firm
delivery poin(s) on a Gas Day, based on conflrrrnable nominations for firm
service within Shipper's Maximum Daily Quantity. I[, due to &n event of Force
Majeure as defined in Section 6.10 of the General Terms and Conditions of this
FERC Gas Tariff, GTN is unable to deliver any portion of Shipper's Firm Daily
Volume hr a period greater than ten (10) conseoutivc days, then for each day
bayord ten (10) days that GTN so fails to provide service the applicable
neservation oharges includ ing applicable rsservation-tra.sed surchaiges shal I not
apply to the quantity of gas not delivered by GTN within the Shipper's Firm
Daily Volume; provided, however, that these charges shall ncrt tr eliminated to
the extent that the Shipper utilizes sscondary point servicc.
Exhibit D - Pipeline Tariffs Page 23 of 55
Cas Transmission Northwest LLC
FERC Cas l-ari,ff
Fourth Revised Volume No. I'A
lssued: December 6, 20r?
Effectivtr: January l2,20l2
PART 5.t.3.10
5. 1.3.1 0-Rate Sched FTS-I
Reservation Chg. Credit - Non-Force Majeure Event
v.5. I .0 liuperseding v.3.0.0
Docket No. RPl2-15-005
Acccpted: January 16, 2013
5.1 .3.I0 Rcservation Charge Credit - Non-Force Majeure Event.
As uSed in this S€ction 5.1-3.t0. Firm Daily Volume shall mean the volurne of
gas whieh GTN is obligated to deliver on a firm basis at Shipper's firm delivery
point(s) on a Gas Day, based on confirmable nominations for primary firm
service within Shippor's Maximum Daily Quantity. Except as provided for in
Seotion 5.1.3.9 above, in the event CTN fails to deliver any po(ion of Shipper's
Firm Daily Volume on any Cas Day under any firm contract, then the applicable
reservaliofi oharges including applicable rsscrvation-based surcharges shall not
apply to the quantity of gas not delivered by GTN within the Shipper's Firm
Daily Volume; provided" however, that these charges shall not be eliminated to
the cxtent that the Shipper utilizes sccondary point servioe.
Exhibit D - Pipeline Tariffs Page 24 of 55
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Rsvised VolumeNo. l.A
lssued: Deaember 6. 2012
Effective: January 12, 2OlZ
PART .5. t.3.1 I
5. I .3.1 I -Rate Sched FT'S- I
Reservation Charge Credit - Confnmable NOminations
v:3;0.0 Superseding v.2.0.0
Docket No. R"Pl2-l 5-005
Aoceptcd: January 16, 2013
5.1 .3.1 I Reservation Charge Credit - Confirmable Nominations.
Any cxemptisn li'om crediting fbr nominated amounts not confirmed, as
provided in Sections 5.1.3.9 and 5.1.3.10 hereof, is limited to events caused
solely by the conduct of others, such as Shipper or upstrearn or downstrcam
facility oporators not contnclled by G'l-N.
Exhibit D - Pipeline Tariffs Page 25 of 55
Gas Transmission Northwest LLC
FERC Gas Tariff
Founh Revised VolumeNo. l-A
Issued: Deccmber 6, 2Al7
Efttctive: January 12, 20t2
PART 5.r.3.12
5. 1.3. I 2-Rate Sched FTS-I
Negotiated Rates
v.0.0.0
5. 1.3. l2 Negotiated Rates.
Notwithstqnding any provision of GTN's Tariff to the contrar], GTN and
Shipper may mutually agree in rvriting to a Negotiated Rate (including a
Negotiated Rate Formula) with rsspect to the rAtes, rate componehts, charges, or
credits that are otherwise ptescribed, required, established, or imposed by this
Rate Schedule or by any other applicable provision of GTN's Tariff.
Such Negotiated Rate shall be set fofth in Attachmcnt B to the F[rm
Transportation Service Agreement and GTN shall make any filings with the
Commission necessary to effe$uate such Negotiated Rate.
Docket No. RPl2-15-005
Accepte* January 16" 2013
Exhibit D - Pipeline Tariffs Page 26 of 55
Gas Transmission Noflhwest LLC
FERC Gas Tariff
Fourth Revised Volume No. I-A
Issued: April I I, 20l l
Effective: April4,20l I
PART 5.I.4
5.1.4 - Rate SehBd F-tS- I
Fueland Line Loss
v.2.0.0 Superseding v. 1.0.0
5.I.4 FUEL AND LINE LOSS
For all Forward Hauls, Shipper shall furnish to CTN quantities of gas for compressor
station fuel, line loss and other utility purposes, plus other unaccounted for gas used in the
operation of GTN's cbmbined pipeline systern between the lnternational Boundary near
Kingsgate, British Columbia and the Oregon-Califomia boundary for the transportation
quantities of gas delivered by GTN to Shipper, based upon the e{fective fuel and line loss
perc€ntages in accordance with Section 6.38 of the Genoral Terms and Conditions. No
fuel charge shall apply to transactions that do not involve a. fsrward haul movement of
gas"
Dockct No. RPI l -198G000
Accepted: Mny 4, 201I
Exhibit D - Pipeline Tarifis Page27 ot 55
Cas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revisad Volume No. l-A
Issued: April l l, 20l l
Effective: April4,20lI
5.I.5 TRANSPORTATION GENERAL TERMS AND CONDITIONS
All of the 'Iransportation Geniral Terrrrs and Conditions are applicable to this rste
schedule, unless otherwise stated in the exccuted Fhm Transportation Seryice Agreement
between CTN and Shipper. Any future modifieations, additions or deletions to said
Transportation General Terms and Conditions, unless othenvise provided; are applicable
to firm transportation servioe rendered under this rate sohedule, and by this refcrence, aie
made a part hereof
PART 5.I.S
5,1.5 - Ratu Sched fTS-l
Transportation Ceneral Terms and Conditions
v.2.0.0 Superseding v. 1.0.0
Dooket No. RFI l-198(:".000
Accepted; May 4- 201I
Exhibit D - Pipeline Tariffs Page 28 of 55
NGTL System
Q r,?,,H:?.[gdu
NGTL $ystem
TransCanada's - NGTL System Transportation Rates
20t3lnterim Rabs Effecttve January l,2013
Rsceipt Ssrvices
EI-B Average Demand Rate (3 yr term; I
lT-R (tnterruptiHa Receipt)
Dellvery S6rviees
FT:D Derfland Rtte {l vrterml 2
Group 1:
EmpresgMcNeiii Eorder
Alberta-B.C. Bader
Gsrdondale Border/Boundary Lk Border
ATCO: ClairmonUshell CreeUEdson
Group 2:
ATCO North FSD poinls
ATCO South F$D points
Alb€rta MontanaAJnity/Cold Lake
All other Group 2 delivery lomthns
Group 3r
ATCO North FSU points
ATGO South FSU pdnts
Allother Group 3 Delivery locations
Page I of5
Terfff Rate lfformauon Furposes
$I10rms SJGJ/d
(Cdn) (cdn)
197.271mo 17.2
7.481d 19.7
S/MMBtu/d
(us)
18.5
21.3
flMcffd
{cdr}
18.4
21.1
Tariff Ret6 lnfotma$on Purpo$es
$rGJ f/GJ/d $iMcfld i/MlulBtu,ld
(Cdn) (Cdn) (Cdn) (us)
5.29rmo
5.38lmo
3.33mo
3.1Ufio
3-39/rno
3.1?mo
3.3Umo
3"1Z/mo
4.12lma
3.74lmo
3.74lmo
17.4
17.7
't0.9
10.3
18,6
18.9
11.7
11.0
18.7
19.1
11.8
11.1
1,t,1
'10.3
10.9
10.3
13.5
12.3
12.3
11.9
11.0
11.7
11.0
12.0
't 1.1
1 1.8
11.1
14.6
13.3
13.3
14.5
13.2
13.2
Exhibit D - Pipeline Tariffs Page 29 of 55
file://C:\IETen:rp\Temporarv IntemeJ Files\Contertt,Outlsok\YxDA4lFU\NCTL System ... 07-22-2013
NGTL System
lT-D (tnterruoiibto Detiverv)
Group 1:
Empress/lrlcNeill Border
Alberta-B.C. Border
Gordondale Bsrder / Bor.rndary Lk Border
ATGO: ClairmsrUshell CraeUEdson
Group 2:
ATCO North FSD points
ATCO South FSD poinfs
Alb€rta Montana/unity/Cold Lake
Aliother Group 2 delivery poinb
lFind more detaile on RecEipt Frim Foints al Receipt Poinr Rates
1-2 yearterm: 105% (Price PointC)
34 yearterm: 100% (Price Poinl B)
5+ year term: 95o/o (Price Point A)
? Ftrnd rnore detalls on Delivery Prioe Points at Deliyerv Foint Rate,s
't*2 yearterm; 100% (Price PointZ)
3-4 yo*r t6rm: 957o (Prlce Point Y)
5+ yearteim: 9OYq (Price Poinl X)
- Rates are payable in Canadian dollars.
FT-R Ritu Ranga
FT-R Floor Rate
FT-R Ceiling ftate
- Rat€s do not include GST.
19.12
19,45
12.M
11.28
1?.26
11.28
12.M
11.28
20.5
zo.8
12.9
12.1
13.1
12.1
12,5
12-1
Page 2 of5
20.6
21.0
13.0
12.2
14,2
12.2
r3.0
12.2
Page 30 of 55
07-22-2013
- For billing purpose+,lO'mr units arg used to Receipt SeMoes and GJ units are for Delh&ry seMces
- tvtc{ and MMBts units are proviried fsr illustrative purposqs anly.
- Cohversion factoc betow have bcen used to calsulaG the rales Provided fql information purpeses:
Cdn$tuSS 0.9S - subject to change (updated Od 9; 2012)
$/GJ to p/t4MBtu '1.06
$Il'O'nrir to 6lGJ 37.8 MJ/rni
rAdual heating value is dependent upon speciltc receipt or delivery points and ranges fiom 36,0 [ruim3 to 44,0 MJlm3,
$rl0tnn d/GJrd d/Mcf/d fltlMBtu/d
111.37/mo 9,7 10.4 10.4
283.171mo 24.6 28.4 26.6
2S'!2 lnterim Rates Effuctive January 1, t012
Exhibit D - Pipeline Tariffs
file://C:\lll'Iernp\Tenrporary lnternet Files\Content.Outlook\YXDA4l FU\NGTL
NGTL System
HecelptServlces
FT-R Average Demand RatB (3 yr term) 1
lT-R (lntenuptible Reoeipt)
Detlvery Sarvlces
Ff8 Demand Rate (1 vr terml 2
Group 1:
Empress/McNeill Border
Alberta-B.C. Border
Gordondale Border/Boundary Lk Border
ATCO; ClairmonU$hell CreeldEdson
Group 2:
ATCO North FSO points
ATCO South FSD points
Alberta Moiltana/UnitylCold Lake
All other Group 2 delivery locathns
Group 3:
ATCO North FSU points
ATCO South FSU points
All other Group 3 delivery locations
tT-D { tilenundbte Deliverv}
Gruup 1:
Em press/Mc'l'leill Eorder
AtberttB.C. Border
Gordondale Border / Boundary Lk Border
ATCO: ClainnonU$trell CreeUEdson
Tariff Rate lnformation Purposes
$rternr 6rGJ/d
(cdn) (cdn!
179.941mo 15.6
6.78/d 17.9
Page 3 ofS
6ttficttd drlllMBturd
(cdn) (usl
16.7 16.0
19.2 18.3
lnformation Purposes
illrircftd dfMt{Btt"t/d
{Cdn} (US)
Terlff Rats
$GJ
{Cdn)
5.3oIrfio
5.51/mo
3A4lmo
23$mo
3.39/mo
2.39-/mo
3.44lrno
2.39lmo
4.1?/fi\o
2.87lmo
2.87/mo
,JG.I/d
(cdn)
17.4 18.6
18.1 1E,3
11.3 12.1
7.8 8.4
19.1,|
19.86
12.42
8.6,|
11.9
8.4
12.1
8.4
14"5
10.1
10-1
20.5
21.3
r3.3
9.2
17.8
18.5
11.5
8.0
11.4
8.0
11.5
8.0
19.5
20,3
12.7
8.8
11.1
7,8
11.3
7.8
13.8
s3
9.6
13,5
9.4
9.4
Exhibit D - Pipeline Tariffs Page 31 of 55
fil*//€llEl'ernpYlemporery IntemetFiles\Contenloutlook\YxDA4lFUNGTL Systern... 07-22-2013
NGTL System
Group 2:
ATCO North FSD points
ATGO Soulh FSD points
Alberta MontanalUn ity/Cold Lake
All other Grcup 2 delivery points
lFind more detaiis on Receipt Frie Points at Rec€ipt Pc,rint Bates
1-2 year teni: 105% (Price Point C)
34 yearterm: 100% (Price Poirrt B)
5+ yesrtgnn: 95o/o (Prixi Point A)
a Find mare d6teiB on Delivery Price Points al D6liverv FoiH Ratss
t-2 year term: 1007o (Price Palnt Z)
3-d year term: 95e/o (Price Poinl Y)
5+ year term: 900/o (Price Point X)
- Rates are payable in Canadian dollars.
- For bllling purposes,l0'm' units are usdd io Receipt Services and GJ unils are for Delivery Eerviceg
- Mcf and Mt{lBtu unie are provlded for illushattue Furpoees only.
- Conversion faciord bclsrrl havg been use{ to calGulate the rates provided for information purposee:
12.26
8.61
12.42
8"61
13,r
o,
13.3
9.2
#nfiMBturd
8.3
23.6
Page 4 of5
12.5
8.8
12,7
8.8
Cdn$/lJS$
f/GJ to C/MMtstl
$/loW to 6lGJ
FT-R Ffate Ranga
FT-R Floar Rats
FT-R Ceiling Rate
- RaEs da not include GS
1.03 . subjert to change (upd6ted O(iober 7, 2011)
1.06
37.8 MJ/ms
-Actrral heatirry value is dependerrt upon specific receipl or delivery points and ranges ftom 36.0 MJ/m3 to 44.0 MJ/m3,
Other information for TransCanada's NGTL System:
Current
ReceiBt Po-iot Eates
$r10:m' $/GJ/d (l$cftd
93.81/rno 8.1 8.7
266.07/mo 23.1 24.7
Archives
EEcelotFoint Rates
Exhibit D - Pipeline Tariffs Page 32 of 55
frle://C:\tETemp\Tempora,ry Intemel, Files\Content.Outlook\YXDA4lFLANGTL System ... A7-2?-2013
NOTL System
Fuel Rates
AB Bsrder Heat Values
Deliverv Point Rates
Page 5 of5
Fuel Fiatas (20ft1- 2010) (Zz KB, XLS)
Fuel Ratas f2000 - 2@4 (41 KB. DoC)
AB Border Heat Values {61 KB. PDF)
Disclaimer:
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Pago Updated: 201343-12 16;21:'l3h CT
Cuslorner Express Home r Pricing & Tollt n HGTI Sy*tom
Copyright 6 201 3 TransCa nada FipeLines Limited
Exhibit D - Pipeline Tariffs Page 33 of 55
file:/lC;\IETemp\Temporary Intemet Files\ContenLoutlook\'YXDA4IFI"ANGIL Systern ... 07-Z:2-2913
Foothills Pine Lines Ltd.
Page I
Rate Schedule FT
L
RATE SCTIEDULE TT
rIRM TRANSPORTATTON SERVICE
AVAILABILITY
This Rate Schedule FT, Fifltr Transportation Service is available to any Shipper which
has:
(a)Satisfied all applicable requircments as sst fodr in the Capacity Allocation
Procedures and subsection 5.8 of the General Terms and Conditions of this Gas
Transportation Tariff: and
Executed a Service Agreemenl Finn Transportation Senicc wit'h Company. for a
minimum term of one (l) year ending on the last day of a Month.
(b)
3.
ForZones I and 9 only, Sackhaul qsrvioe, io also available undsrRate $chodulc FT, Firm
Transportati on Serv i ce.
APPLICABILITY
This Rate Schedule FT. Firm Transportation Service shall apply to all transportation
services under Shipper's Service Agrecment, Firm Transportation Servicc other than
service specifically provided fbr in another rate ochedule, as of the Billing
Cornmencement Date, whether or not gas is fictually Sansported.
SERVICE DESCRIPTION
Service rendered by Company for Shipper under this Rate Schedule F'f, Firm
Transportation Scrvice consists of:
(a) The receipt of gas from Shipper (or for Shipper's sccount) at each Receipt Point
as specified in thp Servic-e Agreernent, Firm -fransporJation Service;
TARIFF'* PI{ASE I
Exhibit D - Pipeline Tariffs
Effective Date: April 1,2007
Page 34 of 55
Ytge2
Foothills Pipe Lines Ltd. Rate Schedule FT
(b) The transportation of gas by Company through the transportation system,
described in section 6 hereof and
(c)The dclivery by Company to Shipper of gas nominated by Shipper (or for
Shipper'g account) at each Delivery Point specified in the Senrice Agreement,
Firm Transportation Service.
4, SERWCE AGREEMENT
This Raw Schedule FT, Firm Transportation Seryise is subject to all ter-ms, conditions,
stipulations,and prov isions of tfte Service A greement, Firm Transportation Serr ice.
GENERAL TERMS AIYD CONDITI.ONS
This Rate Schedule FT, F.irm Transportation Service is subject to all terms, conditions,
stiptilations and pmvisions of the Ceneral Teims and Conditions of this Gas
Transportation Tcriff.
SUBSTDIARY COIVIFANIT,S AN} ZONUS
General
Cornpany's hatrsportatiorr system consists of opoating segments with each segment
operated by a Subsidiary Company. Cumpany and Subsidiary Companies have enterod
into transportation agrecments for provision of transpofiation services by Subsidiary
Companies for Company. Copies of the appliccble transportation *greements are
attached hereto as Supplements I through IIL Each Subsidiary Company shall divide its
segment into one or more Zones as defined in Schedule I, Annex ll ol'the Northern
Pipeline Act and desuibed in subsection 6.2 hereof, Shipper, through its Service
6.
6.1
Effectivc Date: April 1,2007,TARIFH-- P}IASE I
Exhibit D - Pipeline Tariffs Page 35 of 55
Foothills Pipe Lires ttd.
Fage 3
Rate Schedule FT
6.2
Agreement, Firm Transportation Service wi*r Company, shall oontract to havE its gas
transported through one or more of these Zones.
Description
The Subsidiary Companies listed below own and operate the portions of the Phase I gas
transportation system sst opposite the name of each such Subsidiary Company.
Subsidit{v Comoany Zone No.
Foothills Pipe Lines 6
(AIta.) Ltd.
Foothills Fipe Lines
(South B.C.) Ltd-
Footfiillq Pipe Lines
(Sask.) Ltd.
Deqcriptio,Ir
From CarolinB, Alberta to the
Alberta/ Saskatchewan border
near Empress, Alberta.
From Caroline, Alberta to the
Alberta/B.C. border near
Coleman, Alberta.
r24.03
From fie Alberta/B.C. border 170.7
near Coleman, Alberta to the
B.CJU.S. border near Kingsgate,
B.C.
From the Alberts/ Saskatchewan 258,97
border noar Emprcss, Alberta to
the Saskatchewan/U,S. border
near Monchy, Saskatchewan"
I-cngth
fkm)
378.49
7.
7.1
CIIARACTEROF SERWCE
Sirm Transportation Scrvice
Gas transported by Cornpany for Shippar ender this ltate Schedule FT, Firm
T'ransportation Service shall not be subject to curtailment or intsrruption exoept as
provided in subsection7.2.4 h*ein and in the GenEral Terms and Cqnditions of this Gas
Transportation Tariff.
Eflbctive Datc; rtpril l,?007TARITF * PHASE I
Exhibit D - Pipeline Taffis Page 36 of 55
Foothills Pirre Lires Ltd.
Page 4
Rate Schedule FT
7.2 Receipt and Delivery Obligations
72.1 At each Delivery Point" Company and Shipper shall establish the Maximum Daily
Delivery Quantity ('MDDQ") and shall specify theportion of such MDDQ to be
rscelvcd at caeh Receipt Point The aforementisned MDDQ and portions thereof
shall be speeified in Appendix A to the Service Agreernent, Firm Transportation
Scrvicc.
7.3,.2 At each Delivery Point, identified in Appendix A to the Service Agreernent, Firm
Transporktion Service, Company is obligated to deliver to Shipper a daily
quantity of gas which has an aggregate energy content of atl gas received from
Shipper at each Receipt Point destined for such Delivery Point, less Shipper's
share for each Zone of the energy content of Company Use Cas used in the
transportation of suoh gas on su.eh d4y.
$lripper's shere shall be calculated pursuf,nt to seotion 8 of thE General Terms and
Conditions of this Gas Transportation Tariff.
7 2.3 Notwithstanding subsection7.?.7 here in, Shipper shallnot be allqcated a share of
Company Use Cas in respect ofBackhaul service.
7,2.4 Company will provide Backhaul service underthis ltate Schedule FT, Firm
Trarsportation Scrvice fo Shipper ori Zoncs I and 9 only in circumstances wherc
such service is requested by Shipper and. in Company's judgemen! tfiere is
suflicient quantiry of gas bcing received into Company's system to eneble suoh
service to be provided.
Daily Gas Nominrttions
73.1 Shipper shall advise Company, in witing, of the tiqtal daily quantity of gas
nomirl*ed by it flor oach Delivery Foint, Such tota[ daily quantity of gas shall
no{ subject to Aflicle 1"2 of Shlpper"s Service Agreemenl, Firm 'l'ransportation
Sertrice, exceed thc MDDQ for each such Dplivery Point.
Effcctive Date: April 1,2007
73
TARI}.'F _ PHASE I
Exhibit D - Pipeline Tariffs Page 37 of 55
8.
8.r
Page 5
Foothilis Pipe Lines Ltd. Rate schedule F.T
7.3.2 Out of such lotal daily quantity of gas nominated for each Delivery Point, Shipper
shall advise Company of the daily quantity of gas nominatsd by it for
transportation from each Reoeipt Point.
733 Shipper may provide its nomination ttrrough written confirmations received by
Company from a downstream carrier. Company shall rely on such confirr-nations
received ftom downstream carrier to determine Shipper's nomination quantities at
Delivery Points. For cerlainty, this would include Shipper's wriften confirmation
received by Company from Northern Borderor Gas Transmission Northwest.
CT{Afi,GE FOR SERVICE
The rate used in calculating Shipper's monthly bill for Service under Rate Schedulc FT,
Firm Transportation Service in the Zone is the FT Rate.
Shipper's Obligation to Pay
Shipper shall be obligated to pay to Company in respect of each Billing Month, a charge
for services rendergd hereunder being tho aggregate of Shipper's monthly dernand
oharges determined in accordanco wjth strbseotion 8.2.1 hereof and Shipper's Surcharge
determined in accordance with subsection 8,2.2 hereof. Shipper's obligution to pay is not
subjectto any adjustnent or abatement under any cirrumstancs$ except as specifically
provided for irr section t hereofl and such obligation shall be billcd by Cornpany to
Shipper in ascardancc with section 5 of the Cenoral Terms and Conditions of this Cas
Transportati on "fariff.
Monthly Charges
8.2.1 Moathly Demand Charge
Shipper's monthly demand charge for a Billing Month slrall be the product of:
Effcotivc Date: April 1.2007
8.2
TARIFF.PHASE I
Exhibit D - Pipeline Tariffs Page 38 of 55
Foothills Pipe Lines Ltd.
Pagc 6
Rate Schedule F'T
(a)Shipper's MDDQ as indicated on Schedule A to Shipper's Ssryise Agreemertt,
Fimr Transpofiation Service for such billing month;
Shipper's Flaul Distance for the Zone; and
the FT Rate for the Zone.
(b)
(c)
&3
8.2,2 Monthly Surcharge
Shipper's surcharge atnornt, if any, shall be an amount to recogniz.e the recovery of cosg
associatsd with special tacilities installed by Company lbr Shipper agreed to between
Company and Shipper expressed in dollars per month. $uch amount shall be set ow on
Schedule A to Shipper's Se.rvice Agreement, Firm Transportation Service.
Allocation tlf Gas Delivered
Notwithstanding ani otlrer provision of this Rate Sohedule FT, Firm Transportation
Service, and any Service Agrecment or the General Terms and Conditions of this Gas
Tr?rnsportation Tariff, and witlrout regard tO how gas may have been nominated, the
sggregate qusntity of gas deliyered to a Shipper at the Dellvcry Point during any Billing
Month shall be allocated for billing purposes as follows:
(a)first to sewise to Shipper under Rate Schedule STFT, Sho* Term Firm
Transportation Service to a rnaximum of the aggregate MDDQ for such Delivery
Point under such Rate Schedule STFT, Short Term Firrn Transportation Service;
sEcond to service {:o Shipper under Rnte Schedule FT, Firm Transportation
Service to a maximum of the aggregate MDDIQ for such Delivery Poirrt under
Rate $chedule FT, Firm Transportation Service; and
third, fsrZqne I and Zoneg to service to Shipperunder Rste Schedule IT,
Intenuptible Service and for Zane 6 and Zsne 7 to Shtpper urtder Rate Schedutre
OT, Ovemrri Transportation Service.
(b)
(c)
Effective Date: April I,2007TARIFF * PHASE I
Exhibit D - Pipeline Tariffs Page 39 of 55
Foothills Pipe Lises Ltd.
Page 7
Rrte Schedule F"T
8.{Charge for Over-Run Gas in Zone I and Zone 9
In the event that Company determineg in respect of a Billing Month, that Shipper has
tendered for transportation, and Company ha.s transported for Shipper, a quantity of gas
in excEss of the MDDQ as indicated on Appendix A of Shipper's Servioe Agreemcnt,
Firm Transportation Service, Shipper shall pay Company an amount equal to the product
of a quantity of gas equal to such excess and the IT Rate for Service under Rate Schedule
IT, [ntemrptible Transportation Service.
Accounting
Company shall mainlain books of account in accordanoe with the requirernents of the
National Energy Board and, to the extent not inconsistent with such requirements, in
acc.ordance with generally aocepted accounting principles in Canada.
rA[LtiRE TO D,ELIVER GAS
General
If Cornpany shall, in any billing month, fail for any reason to make delivery to any
Shipper of the whole or any portion of the quantity of gas nominated by such Shipper
from Company in ascordance with such Shipper's Service Agreernenq trirrn
Trarsportation Service, such Shipper's obtigation to pay Company pursuant to seotion 8
of l{ate Schedule FT, Firm Transportntion Service shall be subject only to thc
adjushrrents exprtssly provided in this qeqtion 9.
Make-Up Grs
In the event that Company fails on any day ts deliver to Shipper at the Delivery Point the
quantity of gas Shipper has in good fai{.h nominated up to Shipper's MDDQ (mless such
failure is due to planned repairs. maintenance, replacoment or othcr upgrading, or other
work related to Company's trartspor{ation .system for which Company gave Slrippers
notice under subsection 8.8 of the Genersl Teims and Conditions) Shipper shall be
Effective Daq April 1.2A07
8.5
9.
9.I
92
TARIFF. PHASE I
Exhibit D - Pipeline Tariffs Page 40 of 55
Page 8
Foothills Pipe Lines Ltd, Rate Schedute trT
entitled, subject to subscction 6.5 of the General Terms and Conditions and within two
years of such failurc, to have Company trensport suoh quantities of gas [n excess of
Shipperts MDDQ sufficient to make-up such defie.iency ("Make-Up Gas") at no
additional demand charge. Demand charges credited to Shipper under subsection 9.4.1
shall be reoovered by Company rcspecting Make-Up Gas.
9J Alloc*tion of Ssrviee
If Company is on any day required to allocate ssrvice pumuant to Article 1.2 of the
Scrvice Agreemenl Firm Transportation $ervice of two or rnors $hippers, Company
shall give priority in such alloeation to quantities of gas desired to bo tendered in respect
to Make-Up Cas over Intemrptible Transpottation Service. .
Bilting Adjustrrrent
9.4.f Dernand Charge Credtt
(a) Subject to subsection 9.4. t(b), if in any month Company is unable to
deliver up to 98 pcroent of ttrc quantily of gas that Shipper has in good
faith nominated up to the IvIDDQ times ths number of days in such month,
then in rcspect of such month, a crcdit shall be applied to the month'ly bill
rendered by Company determincd according to the fbllowing formula:
9,4
FI Rate x Shipper's
Haul
Distance
Shippeds MDDQ Average
Day
Delivery
Quantily+
(b)
'Average Day Dclivery Quantity = Deliveries to Shippcr in any Morfih in which
a DEmand Charge Credit is applicable, divided by the number of days in that
particular Month.
No srsdit to the Monthly bill shall be made if Cor,npany delivcrs less than
98 petcent of the quantity of gas norninated as a rcsult of planned repairs,
maintenance, replacement or other upgrading, or other'*,ork rclated to
Company's transportatiort system for which Company gave firm Shippers
TARIFF _PHASE I
Exhibit D - Pipeline Tariffs
Effective Datel
Page41 of55
9.5
Page 9
Rste Schedule FTFoothills Pipe Lines Ltd.
notice under subsection 8.8 of the Ceneral Terms and Conditions on
Company's Facilities or as a result of Shipper being unable to deliver gas
at the Receipt Point or sccept gas at the Delivery Point.
Erccption
Subsections 9.2 through 9.4 hereof shall not apply to any failure of Company to mtke
delivery to Shipper of any gas nominated by Shipper pursuant to Slripper's Service
Agreement Firm Transportation Servic,e if such failure is caused or contributed to by the
lailure of Shipper to, or to be able to, deliver to or take delivery from Company of such
gas, or by any other action of Shipper or Persons acting on its behalf which causes or
contribut€s to such a failurc by Company.
RENE\ryAL RTGHTS IN Z,oNES 6 7 AND I
l0.l Aveilobitity
Shippers to whorn renewal rights are availablq shall lrave tlre option ("Renewal Option")
of extending the existing term of the Service Agreement, Firm Transportation Service
with respect to all or. if Company agrees, a portion of Shipper's lirm eapacitl, rights
beyond the primary term specified in the Service Agreement, Firm 'lransportation
Service provided that:
(a)Shipper has at any time in the past executed a Service Agreement, Firm
Transportation Service containirtg e term of at least five consocutive years; such
Service Agreement, Firm Transportation Service or any extensions or
amendmcnts tlrerelo or qny amended Esrvioe Agrcement, Firm Transportation
Seryics executd in replacement or in substitution therefore, has not terminated
prior to the exercise of the rcnewat rights granted herein;
Shippcr is not in default with respeet to any of its obligations under its Servise
Agreernent(s), Firm Transportation Scrviae;
I0.
(b)
Effsetive Datc: Aprit 1, ?.007TARIFF_PHASEI
Exhibit D - Pipeline Tariffs Page 42 of 55
Foothills Pipe Lines Ltd.
Page I0
Rate Schedule I{f
(c)lf reguested by Company, Shipper has provided Financial Assuranoes in
accordance with subsection 5.8.1 of the General Terms and Conditions of this Cas
Transportation Tariff; and
Shipper'provides Company, at the time the notice rcferred to in subsection 10.2.1
or l0-2.3 hereof is provided to Company, evidence satisfactory to Company that
Shipper has obained or will be able to obtain appropriate upstream and
downstream fi rm oansportation arangements.
l0.Z Fnacedures
10.2.1 Company may give Shipper notice ('RenewalNotice") not more than 5 years and
nCIt less than slx (6) months prior to termination of Shipper's Service Agreement,
Firrn Transportation Service that Shipper tnust exercise the Renewal Oprion.
Shippcr has ths right to renew the Service Agreement Firm Transportation
Service priorto this Retewal Notie being given upon written notiee to Cornpany.
As long as at least five (5) yeas remain in the term of the Shipper's Service
Agrecment, Firm Transportation Service then such Renewal Notic{ cannot be
given by Company. Shipper has the right to extend its Service Agreemenq Firm
Transportation Service one year dt a tirne to rnaintain a term of at least five (5)
ycars and thereby remain outside the period in which a Renewal Notiee can he
given.
t0,22 Qnce a RenewatNotice is given to Shippea Shipper shatl have ter (10) business
d*ys from tlre dqte of the Renewal Notice to provide Cqmpany with a written
notice from Shipper of Shipper's election to extend the term of the Serviee
Agreernent, Firm Transportation Servioe for a period of at least five (5) years
10,23 IliShipper fails to provide a rwitten request or indicates to Company that it does
not wish to renew its capacity in aecordance with section 10.2.2, thc Company
may moke the capaeity available to othor parties in an Open Season in accordance
with subsection 4.1 of the Capacity Allocatiort procedues of this Cas
Transportation Tariff.
Effeotivs Dato: Aprit l, 2007
(d)
TARIFT. PI{ASE I
Exhibit D - Pipeline Tariffs Page 43 of 55
Fsotftills Pipe Lines Ltd.
Page 11
Rate Schedule FT
103
10.2.4 Upon receipt of all bids for the capacity pursuant to the Open Season in
acoordance with subsection 4.1 of the Capacity Allocation procedures of this Gas
Transportation Tariff, the Company shall se leet the highest net present value
bid(s) and notifo Shipper of the terms of the successful bid(s) within l5 business
days of the close of ttre Open Season. Shipper may rctain this capacity if Shipper
agrees to match the highest net present value bid(s) obtained in the Opcn Season"
In the evenl that such bid(s) is longer than five (5) years, Shipper may retain the
capacity by extending its Service Agreement by a minimum of five (5) years
provided fiat such notics is made in writing to Company within l0 business days
following the date of the bid notification from Company. If no bids are received.
Company may acccpt other terms of renewal if requested in writing from Shipper,
notwithstanding that if the remaining term is less than five (5) years. notice may
be given pumuant to suhsection 1A.2.
10.2.5 Following rcceipt of Shipper's writtcn request in accordancc with either
subsections 10.2.1,1A.2.2 or 10.2.4, Company will, within 5 business days.
provide Shipper witli an amendmentto thc Service Agreement, Firm
Transpoitation Seryiss setting out tlre renewal term. Shippcr shall execute and
return ths amendment to the Servioe Agreetnent, Firm Transportaxion Service to
Company within fifteen (15) business days of receipt from Company, failing
whioh Shipper's Renewal Option terminates.
Shipper shall have Renewal Rights to be exercised in the samo manner and upon the
same terrhs and cnnditions &s sct forth above during any rone$al term.
R"ENEWAL RIGI T$ IN ZONE 811.
ll.1 AvailnLility
Shippers in Zorte 8 shall be enfitled to renew all or, if Company agr6e,s, a portion of
service under a Ssrvice Agreemeng Firm Transportation Service if Shipper gives notice
to Company of such renewal et least one (l ) year prior to termination of Shippor's
Service Agreement, Finn Transportation Service. If Shipper does not provide such
Effcctive Dute: April l, 2007TARIFF-PHASEI
Exhibit D - Pipeline Tariffs Page 44 of 55
Footlills Pioe Lines Ltd.
Page t2
Rato Schedulc FT
notice, service shall terminato on the date qpecified in Shipper's Senrice Agreement Firm
Transportation Serv i ce.
ll.2 Pnocdnrcs
Shipper's notice to rcnew in Zonc 8 pursuant to subseotion I l.l shall be irrevocable fbr
the year imrnediately prior to the terminatiou of ssrvice specified in Shipper's Service
Agreement, Firm Transportation Service.
Any renewal of servioe is subject to the Financial Assurances provisions in subsestion 5.8
of the Generel Tsrms ond Conditions.
$hipper's notice shall specif a renewattenn in Zone 8 ofnotless than one (t) year
oonsisting uf incrennsntS of whole months.
Efl'ective Dat* April l,2007"I-ARIFF * PHASE I
Exhibit D - Pipeline Tariffs Page 45 of 55
Page 8.1
Effective Date: December 1,2009
Westcoast Energy lnc.
TOLL SCHEDI.iLES . SERVICE
TRANSPORTANON SERVICE . SOI'THERN
DEFIN'TIOH$
1. ln this Toll Schedub, the fullouing term shall have the folloaing meaning:
(a) "Enharic - T:So ' ineahs Transpoitation Service - Southe+n yovided
pursuanl tci a $eMce Agreement under which gas is to be delivered to tha
Huntingdon Deflvery Area and, subject to the fulfillment of the conditions specified in
the SeNice Agieement, to fle Kingsgale Export Point
(bl "Kiftosoate Exoort Ppinf' means the point on the intemational boundary between
Canada and the United States of America near Kingsgate, British Columbia, wher:e
the Foothills Pipe Lines (South BC) Ltd. pipeline facilities connec't with the pipeline
facililties of Gas Tmnsmission Northwest Gorpordion; and
(c) "Service Tennn means in resped sf eaeh Firm Transportation Service - Southern
specified in a Firm $ervlce A$eement, the brm of each suci Firm Transportation
SeMce- $suthem as detennined in aocordance with Smlion 3.
All other tefin$ used in this Toll Schedule shall have ffia same meaning as set forth in the
Gener.al Terms and Condftions.
APPLICATIOH
2. This Totl Schedulo applies to all Firm Transportation Service - Southem, AOS and
tntenr'uptibte Transpoffion Service - Sotthem, including lmport Backhaul Service, provided
by lA/estcoast on facilities in Zone 4 under the ptovirbne of a Flrm SeMce Agreement or an
lntemrptible Service Agreenient into which the General Terms and Conditions and this Toll
Schedule are incorporated by refiorenca
3. For all purposes of thls Toll Schedule, the Demand Toll +plicable to any Firm
Transportati,on Service - $outhem provided pursuant to a Firm SeMce Agreement shall be
determined based upon the Service Terrn. and the S6rvice Term for each such service shall
be determined as follors:
(a) in the case of each Firrfl Transpofiation SeMcs - Southem provided for in a Firm
$ervice Agreement efltered into by 6 Shipper with Westcoast prior to November 1,
2005, the number of whole years remaining in the term of each such seMce as of
November 1,2005:
(b) in the case of each Firm Transportition Service - $outhem provided for in a Firm
Service Agreement entered into by a ghipper with Weslcoast after November 1,
2005, the number of whole years in the temr of each such servioe specified in the
Firm ServiceAgreement:
(c) in the case of each such Firm Transportation Service - Southem which is renewed
by a Shipper after November 1, 2005 in accordance with Section 2.06 of the General
Exhibit D - Pipeline Tariffs Page 46 of 55
Page 8.2
Efrective Date: December 1, 2009
Westcoast Energy lnc.
TOLL SCHEDULES . SERVfCE
-Terms and Conditions, the number of whole years in the renetrlal term of each such
service, with effect from the first day of the renewal tdrm; and
(d) in the case of each Firm Transportation Service - Southern provided for in a Firm
SeMce Agrcernenl vutrich is efrendod by the Shipper and Westcoast after
December 31, 2005, the number of whole years rcmaining in the term of each snch
serviee, including the period of the extension, with efiec't from the first day of the
month irnmediately following the 6xecutisn by the Shipper of an amendment to the
Firm $ewice Agreement provirling for suctr extenslon.
MONTHLY BILL. FIRIN TRANSPORTATIOT{ SERVICE . SOUTHERN
4. The amount payable by a Shipper to Westcoast in respect of Fimn Transportation Service -
Southern proMded in any month pursuant to a Firm Service Agreement shall be an amount
equalto:
(a) the product obtained by multiplying the Confact Demand for Firm Transportation
Servica - Southern specified in the Flr6 Serube Agreement by the applicable
Dernand Toll specified in Appendix A fOr Firm Transportation Service - Southem; and
(b) the amount of ta* on fuel gas csnsumed in operations. Fayab& undar the Motor Fuel
Tax Act (Brtish Columbia) afld tha Carbon T-ax Act (British Golumbia) which is
allocated to Shlpper by Westcoast for the month,
less the arnount of any Confact Demand Credits to vr*rich the Shipper is entftted for the
month pursuartt to the General Terms and Gonditions.
MONTHLY BILL - AOs, II'ITERRUPTIBLE TRANSPORTATIOH SERVICE - SOUTIIERN AND
IM PORT BACKHAUL SERVICE
5. lf on any day Shipper has unutilized Firm Transportation Service - Southern at a Delivery
Point in Zane 4 and wsuld incur on such day tolls for AOS and lntemrptible Transportation
Service, other than lmport Eackhaul SeMce, at that Delivery Point or at any other Delivery
Foint in Zone,4, then, notwithstanding the provisions of the General Terms and Conditions
and for the sola purpose of determining th6 amouht of the Commodtty Tolls payable by
Shipper in accqidance lyith this Toll Schedule fsf AO$ and lnteruptibh Transportatiort
Service - $outhern, thetoltowing rules shallapply:
(a) firstly, in the case where ShipBer r,lrould othenvise incur tolls on such day for AO$ and
lnterruptible Transporbtion $eMce - Southern at a Detivery Poinl where Shipper has
unutilized Firrfl Transportation Service - Southem, $hipper shall be deemed to have
utilized Firm Transportatlsn Service at such Delfuery Point 0n such day in ressect of a
volume of gas not exceeding the volurne of unutilized Firm Transportation Service at
such Delivery Pqint;
(b) secondly, in the case where a Delivery Point at which Shipper has unutilized Firm
Transportation Sorvice - Sbuthem is within the Huntingdon Delivery Area and Shipper
has any remaining volume oJ unutilized Firm Transportation Service at such Delivery
Point after apply'ng the rule set out in paragraph (a) above, then $hipper shall be
deerned to have made a diversion on such day pursuant to Sec{ion 7,01(a) of the
Exhibit D - Pipeline Tariffs Page 47 of 55
Page 8.3
6.
Westco5st Energy lrtc,
TOLL SCHEDULES - SERVICE
General Terms and Conditions of a volume of gas not exceeding the amount of the
remaining volurne of unutilized Firm Transportation Service, from that Delivety Point
to any other Delivery Polnt within the Huntlngdon Delivery Area at which Shipper
would otherwise inctlr tolls for AOS and lnteruptible Transportdion Service -
Southem;
(c) thirdly, if Shipper has arry remaining volume of unutilEed Firm Transportation Service
- Southem at any Delivery Point afier applyrng the rules set out in paragraphs (a) and
(b) abole, then $hipper ohall be deemed to have made a diversion on such day
pursuant to Sestion 7.01(c) of the General Terms and Conditions of a volume of gas
not exceding the amount of such remaining volume of unutilized Firm Transpofiation
SeMce from such Dalivery Point to the nearest Donnstream Delivery Point at which
Shipper would otherwise incur tolls fOr AOS and lntem:ptible Transportation Servica -
Southem; and
(d) fourthly, ff Shipper has any remaining volume of unudlized Firm Transportation
Service - Southern at any Dellvery Point after applying the rules set out in paragraphs
(a), (b) and (c) above, then Shipper shall be daemad to have made a diwrsion on
such day pursuant to Section 7.01(b) of the General Terms and Conditions of a
volume of gas not exceeding the amounl of such remaining wlume of unutillzed Firm
Transportation Servic€, frerit such Delivery Point CI the neareet Upstream Delivery
Point at whlch Shlpper Woud otherwise incur tolls for AOS and lntemlptible
Transportation SeMce - Southern-
The amount payable by a $hipper to Westcoast ln respect of AOS and lntenuptible
Transportation Servioe - Southern, inoluding lmport BackhaulService, provided on each day
in a month shall he an amount equel to the sum of:
(a) the product obtaine.d !y multiplying the applicable Commodity Toll specified in
Appendix A for AOS and lntemrptible Transportation Service - Southem or lmport
Backhaul Service by the Receipt Volume for such AOS and lntemtptible
Transportation SeMce (deteffiined after applyin$ the rules $et out in Section 4), al
the point from whiCh:the residue gas is sourced, which is themially equivalent to tha
volufie of residue gas (i) delivered to or for the account of $hipper at tho Delivery
Point, or (ii) transrfiitied throqgh Zone 4 for the account of Shipper on sach such day
during the rnonth;
(b) the product obtained hy multiplying the difference between the Commodity Tolls
specifted in Section 7.03 of the General Terms and Conditions by the vslume of gas
deemecl to be diverted to a Downstream Delivery Point in accordanee with Section
4(cI on each such day durinE the month: and
(c) the amount of tax on fuel gas consumed in operatlons payable under the Motor Fuel
Tax Aci (British Columbia) and the Carbon Tax Act (British Columbia) which is
allocated to Shipper by Westcoast for each day in the month.
Effective Date: December 1, 2009
Exhibit D - Pipeline Tariffs Page 48 of 55
Page 8.4
lnc.
TOLL SCHEDULES . SERVICE
APPENDIXA
DEMAND AHD COTfiNilODITY TOLLS
TRANEPORTANON SERVICE - SOUTHERH
Flrm Transportatlon Servioe - Southern
SeMoe Term
Demand Tolls
$/lolmsimo.
TErasenPNG lnland Huntngdon Kingsvale to
Deliverv Point Delirerv Area Dellrery Area' Huntingdon"
1 yeat
2 years
3 years
4 years
5 years or more
No!6ntb6r tg Mafch
Aprfl to October
14'1.91
137.78
133:65
132.27
130.8S
338.95
s35.42
583.66
577.58
254.W
247.23
u4.74
242.1s
363.67 8a6.21 262.55
353.08 607,97
uz,N 589.74
I To be inoreassd to thd percentage amount of tle applicable toll spocified in a Service Agreement for
Enhanced T-Sotrft SeMce
" For Firm TransporEton SeMce - Southern provfided by Wo$tcoast pursuant to a Firm Service Ag.reement
datsd Apdl 15, 4002 be{weEn Westcoast and Terasen Gas lnc.
Flus the amount of tax on fuel gas consumed in operations payable under the Mstor Fuel Tax Act
(British Columbia) and the Carbon Tax Act tBritish Columbia) which is alloc"ated to Shipper by
Westcoast for each day in the month.
AOS and I ntemrptible Tm ns portation Serv lce - Southem
Commoditv Tolls
$l103;'
TerasenHuntingdon Kingsvaloto
Delivery Area HuntirlEdon'
PNG lniartd, Morths Deli\rery Point Detlverytuea
6.171
4.628
'lF.A.!2
11.859
27.227
20.420
11.415
8.561
' FoTAOS provided byW*taoast pursuantlo a Firm SeMce Agreementdated April 15, 2002 between
Westcoast and Terasen Gas lnc.
Ptus tha amount of tax on fuel gas consumed in operations payabte under the Motor Fuel Tax Act
(British Cslumbia) and the Carbon Tax Ac{ (British Columbia) which is allocated to Shipper by
Westcoast for each day in the mqnth.
Effective Date:July 1, 2013
Exhibit D - Pipeline Tariffs Page 49 of 55
Page 8.5
-
TOLL SGHEDULES - SERVICE
lmport Backhaul Service
Commoditv TollE
$/Jo3ri13
Mbnths Dellvery Area Deliverv Polnt Station No- 2
November &0 March 11 .415 21 .056 27 -227
April to October 8.561 15.792 20.42A
Plus the amount of tax on fuel gas consumed [n operations payable under the Motor Fuel Tax Act
(British Cotumbia) and fte Carbon Tax Aet lBrttish Colu,mbia) whieh is allocated to Shipper by
Westcoast for eactr day in the month.
Effective Date:July 1, 201 3
Page 50 of 55Exhibit D - Pipeline Tariffs
# 100408 Page I of3
# 100408
FORM OF SERVICE AGREEMENT
(Applicable to Servicc mder Rate Schedule SGS- I )
THIS AGREEMENT, made and cntercd into ihis I8 day of May, 1997 by and between NORTHWEST PIPELINE
CORPORATION, a Delaware corporation, hcreinaftercalled "'franspor"tgr," and THE WASI{INGTON WATER POWER
COMPANY hereinafier called'Shipper. "
In consideratign 9f the muhral covenanls and agreernents as herein set forth, *re parries hereto agree as follows:
ARTICLE I - OAS TO BE STORED AND DELIVERED
Subject tothe teflns, corrdifion$,.arrd limihtions hereofand ofthe applioiblq Rat6 Schedule SGS-1, Transporter
agrees to inject" store, and withdraw for delivery to Shipper, and Shipper agrees,to receive from Trausporter, the following
quantities of natural gas:
Up tp a Storage Demand Yolums of 125467,Dt}r$,
Up to a Stor'age Capacity of2906?66 Dths,
Up to a Best Elforts Volume of 24604 D*rs.
Provided, ftrr{rer (when applicable).
(Td be included for storagp O t,nar$ or.4ssignres only)
Shipper ewns an undifiided interest in the Ja-cfison Praifit S1o't4ge P,roject (o,r has acquired an assigned interEst ftom anothsr
Owner), and fur tftc purpose o *tis Agresment and of Rate Schedule SG$-tri Stiippet's Owned or Assigned Stsragp Demand
Voltrme shall b6 ---- Ddrs, and Shippe#s Olned or .{ssigncd Storage'Capaci shall be
-
Dths,
ARTICi,E TI * DELIVEH.Y OF GAS
Delivcry of natural gas by Shipper to Transporter for itrjectio,n and by Transporter to Shipper upon withdrawal shall
be at the point of interconnection between. the Jackson Prairie Stomge Project and Northwest's main hansrnission lins,
Shipper shall arrange for redelivery irans,portation to mainline delivery points under Transportei's transportBtion rale
schedules.
ARTICLE M - AP,FLIC.ABLE RATE SCI{EDULE
Shipper agt€es td p4y Transporter for all natural gas service rcndered urdcr fte {cims Of tlris Agrccmcnt irt
accordance with Transporter's Rate Sclredule SGS- I as filed rvith tbe Federal Energy Regulalory Commission (i'FERC"), and
as such rate scheduls rnay be fiended or supe$eded ,from time ts time. This Agrremeht shall be subiect to the provisions of
such rate schedule and the Ceneral Tenns and Conditions applicable thereto on file with the FEIIC artd e,ftbctive from time to
time, whict by this refer€f,rce is incorporated herein and niade a part hereof,
CONTRACT# IOO4O8
ARTICLE IV - TERM Of IIGREEMENT
This Agreemeht shall become effective On Decerirber 15, 1995' or as othenvise ordered by thE Ff RC as rlre effective
date hereo{, and rltalI conrinue in eflect fbr a p*iod continuing tlrrough Octoher } I , I999.
Exhibit D - Pipeline Tariffs
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Page 51 of 55
7fi9t2013
# 100408 I'age I of 3
# 100408
FORM OF SERVICE AGREEMENT
(Applicable to Senricc under Rate Schcdule SGS-I)
THIS AG'REEMENT, made and entered into ihis I 8 day of May, 1997 by and benreen NORTHWEST PIPELINE
COR-PORATION, a Delawar,e corporation, hcreinaftercalled "'lransportrer," and THE WASHINGTON WATER POWER
COMPANY hcreinafter catrled "Shippcr."
In consideration of the mutual covenants and agreements as herein s€t forth, the parties hcreto agree as follows:
ARTICLE I - GAS TO BESTORED AND DELIVERED
SUbject to the tcnns, oonditions, and limitations horcof and of tlie applicabtc Rste Schedule SGS*1, Transporter
agrees to inject" store, and witMraw for delivery to Shipp*" and Shipper agrees,to receive *om Trausporter, the following
quantities of, natural gas:
Up to a Storage Dentand Volume of 125467 Dttrs,
Up to a Storage Capaciqy of ?906?66 Dths,
Up to a Best Elforts Volume of 24604 Dths.
Provided, ftrther (when applicable).
Oo be includrd fur storagc Ownets,or Assigryes- only)
Shipper owns an undivided interest in the Jackson Prairie Storage hoject (or has acquired an assigned interest from another
Owirei), and fuifhe'purpose of $is Agr€cnientaiid of Rate Schedule 8GS-1, Shipper'sOwned orAssigned Storaga Demand
VolurneshalIbe-Dths'andS}rippefsownedor.dssignedStongeCapacityshallbe-Dths.
ARTICI,E II - DXLTVEH.Y OF GAS
Delivery of natural gas by Shlpper to Transportcr for injection and by Transporterto Shipper upon withctrarval shall
be at the point of iuterconnoction bef\yeen the Jackson Prairie Storage Project and Northwest's main ransmfsgion line.
Shipper shall an-dlge for red€livery transportation to mainline delivery poirrts under Transporter-s transportation rale
schedules.
ARTICLE IIT - AT'.PLICABLE RATE SCI{EDULE
$hippe.r agree$ to pay TrarisBort* Ibr all uatural gas sorvice rendenid untler the terms of this Agreemcnt in
accordance rvith Transporte/s Rate .schedule SGS- I as filed with the Federal Energy Regulatory Commission ("FERC"), and
as such rate schedule may be mrended or superseded froiir time to time, This Agr'eement shall be zubject to the pmvisions of
such rate schedule and flre Ceneral Terms and Conditioos applicable thereto on lile with the FERC and effective from time to
tims, which by this reference is incorporated herein and niade,a pilrt hereof.
C0NTRACT# 100408
ARTICLE IV - TERM OF AGREEMENT
This Agreemeirt shsll bccome effective otl, De.cember II 1995 or as otlrenvise orderetl by thE FERC as rhe effective
date hereof" and shall continue in ellect fcr a period continuing th'rough October 31, 1999.
Exhibit D - Pipeline Tariffs
https:/lpassago. will ianrs.com/passage2593 9/logon
Page 52 of 55
7fi9/2$13
# 100408 Page 2 of3
ARTICLE V - CANCELLATION Of PRIOR /{GREEMENTS
Wlien this Agreemsnt takes effect" it $upersedes, cantels and terminater th€ following agrcemen(s):
ARTIC'LE VI _ SUCCESSORS ANDASSIGNS
Tlris Agreement shall be birlding upgn and inweto the benefit of the parties hereto and their respective successors
and assigus.
IN WITNESS WHEREOF, thepa$i@s hercto havo executed this Agreernerrt as sf tho day and year fint above set
forth.
THE WASI{INGTON WATER POWER COMPANY (Ship,pr}
By
Robert Grtber
NORTIIWE$T PIPELINE CORPOR.ATION (Iransporter)
By
Exhibit D - Pipeline Tariffs
https ://nassase -will iams.som/passase2 5939/l'oEon
Page 53 of 55
7t|9/2013
# 100408 Page 2 of3
ARTICLE Y - CANCELLAfION OF PRIOR AGREEMENTS
When this Agreement takes effect, it supersedes, canOels and terminates the following agreemen(s):
ARTTC'LE VI _ SUCCESSORS ANDASSIGNS
this Agrement shall be binding upon and inqre to the benefit of the pailies hereto and thair respoctive successors
and assigps.
IN WITNES$ WIIEREOF, tlre parties heretg havo executed this Agreement as of the day and year first above set
forth,
TI{E WASI{INGTCIN WATER POWER COMFANY (Shiiiper)
By
Robert Gruber
NORTIi U&ST FIPELINE CCIR[,Ol(ATlON (Iransporter)
By
Exhibit D - Pipeline Tariffs
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Page 54 of 55
7lt9l2a13
# 100408 Page 3 of3
Page 55 of 55
lttgnal.j
SPECIAL LA}IGUAGE
tq the
SERVICE AGREEIT{ENT
DATEDMay I8;1997
be,$yeen
NORTH WEST PIPELINE CORPORATION
and
THE WASHTNGTON WATER PoWER COMPANY
Exhibit D - Pipeline Tariffs
hups://passage-williams. coiit/p assage2 59 3 9/lo gon