20120731Application.pdf

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION OF )
AVISTA UTILITIES FOR AN ORDER APPROVING ) CASE: AVU-G-12-0S
A CHANGE IN NATURAL GAS RATES AND CHARGES )
Application is hereby made to the Idaho Public Utilities Commission for an Order approving a
revised schedule of rates and charges for natural gas service in the state of Idaho. The Applicant
requests that the proposed rates included in this Purchased Gas Adjustment (PGA) filing be made
effective on October 1, 2012. If approved as filed, the Company's annual revenue will decrease by
approximately $3.6 million or about 5.4 1%. In support of this Application, Applicant states as
follows:
I.
The name of the Applicant is AVISTA UTILITIES, a unit of AVISTA CORPORATION, a
Washington corporation, whose principal business office is 1411 East Mission Avenue, Spokane,
Washington, and is qualified to do business in the state of Idaho. Applicant maintains district offices
in Moscow, Lewiston, Coeur d'Alene, and Kellogg, Idaho. Communications in reference to this
Application should be addressed to:
Kelly 0. Norwood
Vice President - State & Federal Regulation
Avista Utilities
P.O. Box 3727
Spokane, WA 99220-3727
II.
Attorney for the Applicant and his address is as follows:
David J. Meyer
Vice President and Chief Counsel for Regulatory &
Governmental Affairs
Avista Utilities
P.O. Box 3727
Spokane, WA 99220-3727
III.
The Applicant is a public utility engaged in the distribution of natural gas in certain portions of
Eastern and Central Washington, Northern Idaho and Southwestern and Northeastern Oregon, and
further engaged in the generation, transmission, and distribution of electricity in Eastern Washington
and Northern Idaho.
Iv.
Eighteenth Revision Sheet 150, which Applicant requests the Commission approve, is filed
herewith as Exhibit "A". Additionally, Fourteenth Revision Sheet 155, which Applicant requests the
Commission approve, is also filed herewith as Exhibit "A". Also included in Exhibit "A" is a copy of
Eighteenth Revision Sheet 150 and Fourteenth Revision Tariff Sheet 155 with the changes underlined
and a copy of Seventeenth Revision Sheet 150 and Thirteenth Revision Tariff Sheet 155 with the
proposed changes shown by lining over the current language or amounts.
The existing rates and charges for natural gas service on file with the Commission and
designated as Applicant's Tariff IPUC No. 27, which will be superseded by the rates and charges filed
herewith, are incorporated herein as though fully attached hereto.
VI.
Notice to the Public of Applicant's proposed tariffs is to be given simultaneously with the filing
of this Application by posting, at each of the Company's district offices in Idaho, a Notice in the form
attached hereto as Exhibit "B" and by means of a press release distributed to various informational
agencies, a draft copy attached hereto as Exhibit "E". In addition, a notice will be sent to customers as
a bill insert prior to October 1, 2012, a copy of which is also included in Exhibit "E".
VIII.
The circumstances and conditions relied on for approval of Applicant's revised rates are as
follows: Applicant purchases natural gas for customer usage and transports it over Williams Pipeline
West (d.b.a. Northwest Pipeline Corporation), Gas Transmission Northwest (GTN), TransCanada
(Alberta), TransCanada (BC) and Spectra Pipeline systems and defers the effect of timing differences
due to implementation of rate changes and differences between Applicant's actual weighted average
cost of gas (WACOG) purchased and the WACOG embedded in rates. Applicant also defers various
pipeline refunds or charges and miscellaneous revenue received from natural gas related transactions
including pipeline capacity releases.
IX.
This filing reflects the Company's proposed annual Purchased Gas Cost Adjustment (PGA) to:
1) pass through changes in the estimated cost of natural gas for the forthcoming thirteen months
(Schedule 150), and 2) revise the amortization rate(s) to refund or collect the balance of deferred gas
costs (Schedule 155). Below is a table summarizing the proposed changes reflected in this filing.
Commodity Demand Total Amortization Total Rate Overall
Sch. Change Change Sch. 150 Change Change Percent
Service No. per therm per thin Change per therm per therm Chance
General 101 ($0.02931) ($0.00849) ($0.03780) ($0.00890) ($0.04670) (5.02%)
Lg. General 111 ($0.02931) ($0.00849) ($0.03780) ($0.00890) ($0.04670) (6.31%)
Interruptible 131 ($0.02931) $0.00000 ($0.02931) ($0.00203) ($0.03134) (6.06%)
X.
Commodity Costs
As shown in the table above, the estimated commodity cost (WACOG) change is a decrease of 2.9
cents per therm. The proposed WACOG is 33.3 cents per therm compared to the present WACOG of
36.2 cents per therm included in rates.
The Company's natural gas procurement plan uses a diversified approach to procure gas for the
coming PGA year. While the plan generally incorporates a structured approach for the hedging portion
of the portfolio, the Company exercises flexibility and discretion in all areas of the plan based on
changes in the wholesale market. The Company typically meets with the Commission Staff semi-
annually to discuss the state of the wholesale market and the status of the Company's procurement
plan. In addition, the Company communicates with Staff when it believes it makes sense to deviate
from its procurement plan and/or opportunities arise in the market.
Avista has been hedging gas on both a periodic and discretionary basis throughout 2012 for the
forthcoming PGA year (thirteen months). Approximately 60% of estimated annual load requirements
for the PGA year (October 2012 through October 2013) will be hedged at a fixed price, comprised of:
1) 11% of volumes hedged for a term of one year or less, 2) 29% of volumes from prior multi-year
hedges, and 3) 20% of volumes from underground storage. Through June, the planned hedge volumes
for the PGA year have been executed at a weighted average price of $3.09 per dekatherm ($0.309 per
therm).
The Company used a 30-day historical average of forward prices (ending July 19, 2012) by supply
basin to develop an estimated cost associated with index/spot purchases. The estimated monthly
volumes to be purchased by basin are multiplied by the (30-day) average price for the corresponding
month and basin. These index/spot volumes represent approximately 40% of estimated annual load
requirements for the coming year and the annual weighted average price for these volumes is $298 per
dekatherm.
Available underground storage capacity at Jackson Prairie represents approximately 20% of annual
load requirements (38% of load requirements during the December to March withdrawal period). The
estimated weighted average cost for all storage volumes is $2.10 per dekatherm. The Company also
utilizes (optimizes) its underground storage capacity to provide additional benefits to customers
beyond the winter/summer price differential and supply reliability.
Overall prices today are lower than what was experienced in 2011. In February 2012, Avista filed an
out-of-cycle PGA with the Commission, decreasing Schedule 150 rates by 5.6 cents per therm (from
41.8 cents to 36.2 cents). The Company believed that re-pricing the non-fixed price portion of its
natural gas portfolio to reflect lower spot prices was appropriate, and was in compliance with the
Commission's Order No. 32471 in Docket AVU-G-1 1-01 to file an application to amend its WACOG
if "gas prices materially deviate" from the previously approved levels. Since that filing, which was
approved by the Commission with an effective date of March 1, 2012, natural gas prices have
stabilized, albeit at a much lower level than this time last year. Cash prices experienced over the
storage injection season (April - September) have also been lower than 2011. This decreased pricing
level has caused the storage WACOG to be lower than what is currently included in rates. With cash
prices lower than levels experienced a year ago the forward prices for the upcoming PGA year, have
also decreased. This decline has provided the opportunity to hedge natural gas through the
Company's procurement plan at a cost below what is embedded in rates.
XI.
Demand Costs
The Demand Costs shown in the table above primarily represents the cost of pipeline transportation to
the Company's system, as well as any known or projected capacity releases. As shown in the table
above, there is an overall slight decrease. Of particular note is the inclusion in the Company's filing of
the effects of the recent Northwest Pipeline rate case which was approved by FERC. While that rate
case caused an overall increase in demand costs for Avista, decreasing costs from the Canadian
pipelines (Alberta and Spectra), and increasing estimated pipeline capacity releases more than offset
the Northwest Pipeline increase.
XII.
Schedule 155 I Amortization Rate Change
As shown in the table above, the proposed change in the amortization rates is an increase in the current
refund rate of $0.00890 per therm. Currently the refund rate is $0.02885 per therm which the
Company proposes to increase to $0.03775 per therm. This increase in the refund rate is driven by the
recent decline in the wholesale cost of natural gas which has resulted in a net refund deferral balance of
approximately $3.1 million. If approved as filed this balance should be refunded to customers over the
next 13 months, assuming normal weather.
XIII.
Inclusive of the Company's Schedule 191 (Natural Gas DSM funding - proposed rate decrease) filing
made July 30, 2012 (see Advice 12-04-U), the average residential or small commercial customer using
60 therms per month would see a decrease of $4.42 per month, or approximately 7.9%. The present
bill for 60 therms is $55.78 while the proposed bill is $51.36. Including the "out-of-cycle" PGA
approved by the Commission in Case No. AVU-G- 12-01, the average residential or small commercial
customer using 60 therms per month would see a decrease of $7.77 per month, or approximately
13.1%, assuming the Company's applications are approved effective October 1, 2012.
XIV.
Exhibit "C" attached hereto contains support for the rates proposed by Applicant contained in
Exhibit "A".
xv.
Applicant is requesting that Applicant's rates be approved to become effective on October 1,
2012. Applicant requests that, if appropriate, the Commission adopt the procedures prescribed by Rule
201-2 10, Modified Procedure. Applicant stands ready for immediate consideration on its Application.
xv'.
WHEREFORE, Applicant requests the Commission issue its Order finding Applicant's
proposed rates to be just, reasonable, and nondiscriminatory and to become effective for all natural gas
service on and after October 1, 2012.
Dated at Spokane, Washington, this 30t1 day of July 2012.
AVISTA UTILITIES
BY
Kelly 0. Norwood
Vice President, State and Federal Regulation
STATE OF WASHINGTON )
) ss.
County of Spokane
)
Patrick Ehrbar, being first duly sworn, on oath deposes and says: that he is the Manager of
Rates and Tariffs for Avista Utilities; that he has read the above and foregoing Application, knows the
contents thereof, and believes the same to be true.
Patrick D. Ehrbar
Manager, Rates & Tariffs
SUBSCRIBED and sworn to before me this 301h day of July 2012.

&' lii rvj4

NOTh \ .
piBUG •)
Az Z
If I I t $
n or Notary ic in for the
lot State of ashington, residing in
Spokane.
AVISTA UTILITIES
Case No. AVU-G-12-O -~>
EXHIBIT "A"
Proposed Tariff Sheets
July 30, 2012
Eighteenth Revision Sheet 150
Replacing
U.C. No.27 Seventeenth Revision Sheet 150 150
AVISTA CORPORATION
d/bfa Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of Idaho 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 43.612* per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
33.285* per therm.
(c)The rate for transportation under Schedule 146 is to be decreased by
0.000* 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 10.327* 33.285* 43.612*
Schedules 111 and 112 10.327* 33.285* 43.612*
Schedules 131 and 132 .000* 33.285* 33,285*
The above amounts Include a gross revenue factor.

Demand Commodity Total
Schedules 101 10.289* 33.162* 43.451*
Schedules 111 and 112 10.289* 33.162* 43.451*
Schedules 131 and 132 .000* 33.162* 33.162*
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.
by Avista Utilities
By Kelly 0. Norwood - Vice-President, State & Federal Regulation
...: ,1JJ
Eighteenth Revision Sheet 150
Replacing
LP.U.C. No.27 Seventeenth Revision Sheet 150 150
AVISTA CORPORATION
dibla_Avista_Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of Idaho 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 43.6112 per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
43.612t 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 10.327 33.285t 43.612
Schedules 111 and 112 10.327 33.285t 43.612
Schedules 131 and 132 .0000 33.285t 33.285
The above amounts include a gross revenue factor.

Demand Commodity Total
Schedules 101 10.289 33.162t 43.451
Schedules 111 and 112 10.289t 33.162t 43.451
Schedules 131 and 132 .0000 33.162t 33.162
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.
ssued July 30, 2012
By Kelly 0. Norwood - Vice-President, State & Federal Regulation
Seventeenth Revicion Sheet 150
Replacing
l.P.U.C. No.27 Substitute Sixteenth Revicion Sheet 150 150
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150
PURCHASE GAS COST ADJUSTMENT - IDAHO
APPLICABLE:
To Customers in the State of Idaho 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 47.392 per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
36.2160 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 11.1760 36.2160 47.392
Schedules 111 and 112 11.17-60 36.2460 47.392
Schedules 131 and 132 .0000 36.2460 36.216
The above amounts include a gross revenue factor.

Demand Commodity Total
Schedules 101 41.1350 36.0920 47.217
Schedules 111 and 112 11.1350 36.082 47.217
Schedules 131 and 132 .0000 36.0820 36.082
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.
February 10, 2012 Effective
y Avista Utilities
By Kelly 0. Norwood - Vice-President, State & Federal Regulation
Fourteenth Revision Sheet 155
Canceling
LPIJ.C. No.27 Thirteenth Revision Sheet 155 155
AVISTA CORPORATION
ri/b/a Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
UITIT"U'll
To Customers in the State of Idaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:
(a)The rates of firm gas Schedules 101 and 111 are to be
decreased by 3.7750 per therm in all blocks of these rate schedules.
(b)The rate of interruptible gas Schedule 131 is to be decreased by
3.5170 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.

Issued by Avista Utilities

By felly Norwood, Vice President, State & Federal Regulation
AJI
I.P.U.C. No.27
Fourteenth Revision Sheet 155
Canceling
AVISTA CORPORATION
dibla Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
155
AVAILABLE:
To Customers in the State of Idaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:
(a)The rates of firm gas Schedules 101 and 111 are to be
decreased by 3.775 per therm in all blocks of these rate schedules.
(b)The rate of interruptible gas Schedule 131 is to be decreased by
3.517 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.
July 30, 2012
y Avista Utilities
By Kelly Norwood, Vice President, State & Federal Regulation
Thirteenth Revicion Sheet 155
Canceling
I.P.U.C. No.27 Twelfth Revicion Sheet 155 155
AVISTA CORPORATION
dlbla Avista Utilities
SCHEDULE 155
GAS RATE ADJUSTMENT - IDAHO
AVAILABLE:
To Customers in the State of Idaho where Company has natural gas service
available.
PURPOSE:
To adjust gas rates for amounts generated by the sources listed below.
MONTHLY RATE:
(a)The rates of firm gas Schedules 101 and 111 are to be
decreased by 2.8850 per therm in all blocks of these rate schedules.
(b)The rate of interruptible gas Schedule 131 is to be decreased by
3.314 0 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.

Issued by Avista Utilities

By Kelly Norwood, Vice President, State & Federal Regulation
AVISTA UTILITIES
Case No. AVU-G-12-O
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
July 30, 2012
AVISTA UTILITIES
NOTICE OF IDAHO TARIFF CHANGE
(Natural Gas Service Only)
Notice is hereby given that the "Sheets" listed below of Tariff IPUC No. 27, covering
natural gas service applicable to Idaho customers of Avista Utilities have been filed with
the Idaho Public Utilities Commission (IPUC) in Boise, Idaho.
Eighteenth Revision Sheet 150 canceling Seventeenth Revision Sheet 150
Fourteenth Revision Sheet 155 canceling Thirteenth Revision Sheet 155
Fourteenth Revision Sheet 155 updates the amortization rate used to refund or recover
previous gas cost differences and Eighteenth Revision Sheet 150 updates the forward-
looking cost of natural gas purchased for customer usage.
These tariffs request an annual revenue decrease of approximately $3.6 million, or about
5.4%.
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, and including the Company's July 30, 2012 rate
reduction request for Schedule 191, the average residential or small commercial customer
using 60 therms per month will see an decrease of $4.42 per month, or approximately
7.9%. The present bill for 60 therms is $55.78 while the proposed bill is $51.36. Larger
commercial customers served under Schedules 111 can expect to see an average decrease
of about 8.5%, with the higher percentages due to lower base rates. However, actual
customer increases will vary based on therms consumed.
This filing requests an effective date of October 1, 2012.
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. Box 3727
Spokane, WA. 99220-3727
July 31, 2012
AVISTA UTILITIES
Case No. AVU-G-12-Oc
EXHIBIT "C"
Workpapers
July 30, 2012
Avista Utilities
State of Idaho
Calculation of Overall Rate Change
Schedule 101
Schedule 111/112
Schedule 131
(currently no customers)
Schedule 132
Schedule 146
Sch 150 Sch 150 Sch 156 Sch 156 Sch 155 Sch 155 Sch 155 Total
Budgeted Gas Cost Gas Cost Gas Cost Gas Cost Amortization Amortization Amortization Amortization Total
Annual Per Therm Annual Per Therm Annual Per Therm Annual Direct Chg Sch 155 Sch 150/155/156
Therms Inc <Dec> Inc <Dec> Inc <Dec> Inc <Dec> Inc <Dec> Inc <Dec> <Refunds> Inc <Dec> Inc <Dec>
54,077,713 ($003780) ($2,044,138) ($000890) ($481,292) ($481,292) ($2,525,430)
20,693,825 ($003780) ($782,227) ($000890) ($184,175) ($184,175) ($966,402)
($002931) ($000203)
440,428 ($002931) ($12,909) ($12,909)
($22,978) ($22,978) ($22,978)
($386) ($386) ($386)
($1,915) ($1,915) ($1,915)
($22,589) ($22,589) ($22,589)
($665,467) ($47,868) ($713,335) ($3,552,609)
$65,712,904
-5.41%
Customer 1
Customer 2
Customer 3
Customer 4
Customer 5
75,211,966 ($2,839,274)
Total Budgeted Annual Revenue
Percent of Increase <Decrease>
Page 1
Avista Utilities
State of Idaho
Average Increase Per Customer (Based on Budget)
Sch Budgeted Average Average
Annual Monthly No. Of
Usage Usage Customers
101 54,077,713 4,506,476 75,118
Basic Charge
111 20,693,825 1,724,485 1,371
First 200
Next 800
Next 9,000
Over 10,000
131
132 440,428 36,702
Average Present Total Proposed Total Estimated Estimated
Mo. Usage Rate Present Rate Proposed Monthly Increase
Per Cust. Cost Cost Increase Percentage
60 $0.85883 $51.53 $0.81213 $48.73
$4.25 $4.25 $4.25
$55.78 $52.98 ($2.80) -5.02%
1,258
$0.86634 $173.27 $081964 $163.93
$0.73419 $587.35 $0.68749 $549.99
$0.65840 $169.87 $0.61170 $157.82
$0.60846 $0.56176
$930.49 $871.74 ($58.75) -6.31%
$0.51725 $0.48591 -6.06%
36,702 $0.55039 $20,200.41 $052108 $19,124.67 ($1,075.74) -5.33%
Page 2
Avista Utilities
Calculation of Idaho Proposed Rates
Sch Description
No.
101 General
111 Large General
First 200
Next 800
Next 9,000
Over 10,000
112 Large General
First 200
Next 800
Next 9,000
Over 10,000
131 Interruptible
132 Interruptible
146 Transportation
Proposed Proposed Proposed Present Present Total
Present Schedule Schedule Schedule Schedule Schedule Proposed
Rate 150 155 156 191 (DSM) 199 (DSIT) Rate
$038679 $0.43612 ($0.03775) $0.02697 $081213
$040806 $0.43612 ($003775) $0.01321 $0.81964
$0.27591 $043612 ($003775) $0.01321 $0.68749
$020012 $043612 ($003775) $0.01321 $0.61170
$0.15018 $0.43612 ($003775) $0.01321 $0.56176
$0.40806 $0.43612 $0.01321 $085739
$0.27591 $0.43612 $0.01321 $0.72524
$0.20012 $0.43612 $001321 $0.64945
$0.15018 $0.43612 $0.01321 $059951
$0.17626 $0.33285 ($0.03517) $0.01197 $048591
$0.17626 $033285 $0.01197 $0.52108
$0.10671 $010671
Page 3
Avista Utilities
Calculation of Idaho Present Rates
Sch Description Present Present Present Present Present Total
No. Tariff Schedule Schedule Schedule Schedule Present
Rate 150 155 191 (DSM) 199 (DSIT) Rate
101 General $0.38679 $047392 ($0.02885) $0.02697 $0.85883
111 Large General
First 200 $0.40806 $0.47392 ($0.02885) $0.01321 $0.86634
Next 800 $0.27591 $0.47392 ($0.02885) $0.01321 $0.73419
1,0001 -10,000 $0.20012 $0.47392 ($0.02885) $0.01321 $0.65840
Over 10,000 $0.15018 $0.47392 ($0.02885) $0.01321 $060846
112 Large General
First 200 $040806 $0.47392 $0.01321 $0.69519
Next 800 $0.27591 $0.47392 $0.01321 $0.76304
1,0001 - 10,000 $0.20012 $0.47392 $0.01321 $0.68725
Over 10,000 $0.15018 $0.47392 $0.01321 $0.63731
131 Interruptible $017626 $0.36216 ($0.03314) $0.01197 $0.51725
132 Interruptible $0.17626 $0.36216 $0.01197 $0.55039
146 Transportation $0.10671 $0.10671
Page 4
Avista Utilities
State of Idaho
Recap of Rate Changes Including GRF
Previous Proposed Increase
Rate Rate <Decrease>
Schedule 150 (Gas Costs)
Schedule 101 $0.47392 $0.43612 ($0.03780)
Schedule 111 $0.47392 $043612 ($0.03780)
Schedule 112 $0.47392 $0.43612 ($0.03780)
Schedule 131 $0.36216 $0.33285 ($0.02931)
Schedule 132 $036216 $0.33285 ($0.02931)
Schedule 146 $0.00000 $0.00000 $0.00000
Schedule 156 (Gas Costs)
Schedule 101 $0.00000 $0.00000 $0.00000
Schedule 111 $0.00000 $0.00000 $0.00000
Schedule 112 $0.00000 $0.00000 $0.00000
Schedule 131 $0.00000 $0.00000 $0.00000
Schedule 132 $0.00000 $0.00000 $000000
Schedule 146 $0.00000 $0.00000 $0.00000
Schedule 155 (Gas Cost Amortization)
Schedule 101 ($0.02885) ($0.03775) ($0.00890)
Schedule 111 ($0.02885) ($0.03775) ($0.00890)
Schedule 112 $000000 $0.00000 $0.00000
Schedule 131 ($003314) ($0.03517) ($0.00203)
Schedule 132 $000000 $000000 $0.00000
Schedule 146 $0.00000 $000000 $0.00000
Combined Schedule 150, 155 & 156
Schedule 101 $0.44507 $0.39837 ($004670)
Schedule 111 $0.44507 $0.39837 ($0.04670)
Schedule 112 $0.47392 $0.43612 ($0.03780)
Schedule 131 $0.32902 $0.29768 ($0.03134)
Schedule 132 $0.36216 $0.33285 ($0.02931)
Schedule 146 $0.00000 $0.00000 $0.00000
Page 5
Avista Utilities
State of Idaho - Weighted Average Cost of Gas
For 10/1/12 - 10/31/13 (13 Months)
Annual System 13 M System Idaho Idaho
Billing Billing Rate System Demand Commodity
Determinants Determinants Per Therm Total Cost Costs (1) Costs (2)
(Therms) (Therms) 30.010% 30.569%
NORTHWEST PIPELINE (Note 3)
TF-2 Demand Charge 29,061,300 31,483,075 $0040220 $1,266,273 $380,009
TF-2 Variable Transportation Charge 54,027,270 $0003000 $162,082 $49,547
SGS-1 Commodity Washington 37,870,120 $0210000 $7,952,725
Idaho 16,157,150 $0210000 $3,393,002 $3,393,002
TF-1 Demand Charge 558,085,000 604,592,083 $0040220 $24,317,147 $7,297,576
End User Cap. Releases 2,555,000 2,767,917 $0040220 $111,328
Variable Transportation Charge 85,225,510 $0.003180 $271,017 $82,847
OTHER PIPELINES
TCPL Alberta (NOVA) Demand 345,375,310 378,263,690 $0.01841 $6,963,790 $2,089,833
TCPL - BC (ANG - FOOTHILLS) 52,564,015 57,028,356 $006618 $3,773,956 $1,132,564
GTN Demand 352,369,710 $000930 $3,275,868 $983,088
GTN Variable Transportation Charge 125,000,000 $000058 $72,500 $22,163
Spectra Energy - Westcoast Energy 35,992,970 38,992,384 $003376 $1,316,483 $395,077
OTHER
Gas Purchases 64,588,630 $038992 $25,184,399 $25,184,399
Capacity Releases ($13,400,000) ($4,021,340)
Terasen Reservation Credit ($6,500,000) ($1,986,985)
GRI Funding $32,000
Total 118,615,900 $58,160,570 $8,256,807 $26,776,973
Estimated Therms 80,251,880 80,745,745
Proposed WACOG $043451 $010289 $033162
Gross Revenue Factor (GRF) 100.3718% 100.3718% 100.3718%
Proposed WACOG Including GRF $043612 $010327 $033285
Present Gas Costs Including GRF $047392 $011176 $036216
Rate Change Including GRF ($003780) ($000849) ($002931)
Sch 101 Sch 101
Note 1-Based on 5 day peak study Sch 111 Sch 111
Note 2 - Annual Commodity Percentage Sch 112 Sch 112
Note 3-Based on a blended rate of current and the NWP GRC Settlement that will become effective 1/1/13 Sch 131
Sch 132
Page 6
Avista Utilities
State of Idaho
Estimated Commodity WACOG
(Based on 30 Day Average Forward Price at 7/19/2012)
Executed Planned Total Cost of Cost of Total
Hedged Hedged Index Idaho Transport Idaho Executed Planned Cost of Cost of Net Idaho
Volumes Volumes Volumes Purchased Fuel Deliveried Hedged Hedged Hedged Index Idaho Purchase
Volumes Volumes Volumes Volumes Volumes Volumes Volumes Comm. Costs WACOG
October 2012 2,798,390 2,744,190 5,542,580 (79560) 5,463,020 $1,124,159 $1,124,159 $668,093 $1,792,252 $032807
November 4,372,410 69,770 5,205,490 9,647,670 (138,220) 9,509,450 $2,375,407 $19,109 $2,394,516 $1,425,642 $3,820,158 $0.40172
December 4,435,420 70,780 2,916,800 7,423,000 (134,540) 7,288,460 $2,409,638 $21,237 $2,430,875 $875,206 $3,306,081 $045360
January 2013 4,346,360 69,360 1,237,640 5,653,360 (106,520) 5,546,840 $2,361,255 $21,451 $2,382,706 $382,789 $2,765,495 $049857
February 3,802,530 60,680 2,995,860 6,859,070 (90,690) 6,768,380 $2,065,805 $18,791 $2,084,596 $927,770 $3,012,366 $0.44506
March 4,401,600 70,240 1,913,880 6,385,720 (55,660) 6,330,060 $2,391,264 $21,677 $2,412,941 $590,675 $3,003,616 $0.47450
April 993,630 686,510 4,207,820 5,887,960 (85,560) 5,802,400 $302,004 $209,134 $511,138 $1,281,846 $1,792,984 $030901
May 584,840 271,700 2,639,370 3,495,910 (49,850) 3,446,060 $190,258 $82,854 $273,112 $804,875 $1,077,987 $0.31282
June 554,050 257,390 1,430,460 2,241,900 (32,250) 2,209,650 $180,240 $78,640 $258,880 $437,045 $695,925 $031495
July 658,480 305,910 1,152,620 2,117,010 (30,110) 2,086,900 $214,212 $94,599 $308,811 $356,440 $665,251 $031877
August 657,840 305,610 1,153,300 2,116,750 (30,850) 2,085,900 $214,005 $94,666 $308,671 $357,244 $665,915 $031925
September 632,070 293,640 1,628,570 2,554,280 (36,550) 2,517,730 $205,621 $91,941 $297,562 $509,923 $807,485 $032072
October 1,099,370 759,560 3,755,150 5,614,080 (80,300) 5,533,780 $341,461 $241,836 $583,297 $1,195,596 $1,778,893 $032146
29,336,990 3,221,150 32,981,150 65,539,290 (950,660) 64,588,630 $14,375,329 $995,935 $15,371,264 $9,813,144 $25,184,408 $0.38992
Page 7
Avista Utilities
State of Idaho
Total Gas Costs Without GRF
For 10/1/12 - 10/31/13 (13 Months)
Demand Commodity Total
Proposed Gas Costs Before GRF
Schedules 101 -112 $0.10289 $0.33162 $0.43451
Schedules 131 - 132 $0.33162 $033162
Present Gas Costs Before GRE
Schedules 101-112 $011135 $036082 $0.47217
Schedules 131 - 132 $0.36082 $0.36062
Increase <Decrease> Before GRF
Schedules 101 -112 ($0.00846) ($0.02920) ($0.03766)
Schedules 131 - 132 ($0.02920) ($0.02920)
Proposed Gas Costs Including GRE
Schedules 101 -112 $010327 $033285 $043612
Schedules 131 - 132 $0.33285 $0.33285
Present Gas Costs Including GRE
Schedules 101 -112 $011176 $036216 $0.47392
Schedules 131 - 132 $0.36216 $0.36216
Increase <Decrease> Including GRE
Schedules 101 -112 ($000849) ($002931) ($0.03780)
Schedules 131 - 132 ($002931) ($0.02931)
Page 8
Contract Number
Contract Demand of
Number Rate Schedule (Dth's) Days
100010 TF-1 Firm Transportation 133,270 365
100164 TF-1 Firm Transportation 10,000 365
100314 TF-2 Jackson Prairie 7,962 365
136948 TF-1 Firm Transportation 5,000 365
136950 TF-1 Firm Transportation 5,330 365
Total Firm Transportation
Less: TF-2 Jackson Prairie
Less: End User Capacity Releases
Net TF-1 Firm Transportation
Annual Daily Daily Annual 13 Month
Contract Rate Rate System System
Demand (Note 1) (Note 2) Costs Costs
(Dth's)
48,643,550 $0.37883 $0.41000 $19,564,801 $21,195,201
3,650,000 $0.37883 $0.41000 $1,468,057 $1,590,395
2,906,130 $0.37883 $0.41000 $1,168,867 $1,266,273
1,825,000 $0.37883 $0.41000 $734,029 $795,198
1,945,450 $0.37883 $0.41000 $782,475 $847,681
58,970,130 $ 23,718,229 $ 25,694,748
(2,906,130) (1,168,867) ($1,266,273)
(255,500) (102,764) ($111,328)
55,808,500 $ 22,446,598 $ 24,317,147
Avista Utilities
State of Idaho
Northwest Pipeline
Note 1 - From NWP Third Revised Sheet No. 5, Fifth Revised Volume No. 1
TF-1, Large Customer, System-Wide (MMBTu) currently in effect.
Note 2 - From NWP GRC Settlement, new rates will become effective 1/1/13
Page 9
Avista Utilities
State of Idaho
Gas Transmission NW Corporation
FTS-1 FTS-1
F-00177 F-00177
(Oct - Mar) (Apr - Sept)
FTS-1 FTS-1 System
F-00178 F-002591 Total
MMBTu's 54,823 30,000 20,782 25,000
Number of Effective Days (13 Mos) 213 181 396 396
13 Months MMBTu's 11,677,299 5,430,000 8,229,672 9,900,000 35,236,971
Daily Non-Mileage Rate (Note 1) $0039216 $0.039216 $0.039216 $0.039216
Mileage Rate (Note 1) $0.000498 $0.000498 $0.000498 $0000498
Mileage 103.39 102.96 117.22 108.29
Total Mileage Rate $0.051490 $0.051270 $0.058380 $0.053930
Fixed 13 Month Amount $457,937 $212,943 $322,735 $388,238 1,381,853
13 Month Mileage Based Amount $601,264 $278,396 $480,448 $533,907 1,894,015
Total 13 Month Amount $1,059,201 $491,339 $803,183 $922,145 $3,275,868
Note I - Gas Transmission NW, Fourth Revised Volume No. 1-A, Part 4.1
Effective 2/07/12
Page 10
Avista Utilities
State of Idaho
TransCanada Pipeline - Foothills (ANG)
Daily Annual 13 Months
Daily Annual KM Mileage Mileage
Contract Contract No. of Contract Rate KM Costs Costs
Demand (Gj) Mos Demand (Gj) (Note 1)
AVA- F8 (Firm) 31,100 12 373,200 $001675934 170.7 $1,067,658 $1,156,630
AVA-F4 (Firm) 58,284 6 349,704 $001675934 170.7 $1,000,440 $1,167,180
AVA- F4 (Firm) 31,892 6 191,352 $001675934 170.7 $547,423 $638,660
AVA-F2 7,159 6 42,954 $001675934 170.7 $122,884 $143,365
AVA-F8 22,508 12 270,096 $0.01675934 170.7 $772,696 $837,087
AVA-F8 (Firm) 16,441 12 197,292 $001675934 170,7 $564,417 $611,452
AVA-F6 (Firm) 16,817 12 201,804 $001675934 170.7 $577,325 $625,435
184,201 1,626,402 $4,652,843 $5,179,809
Canadian Exchange Rate 100% 100%
$4,652,843 $5,179,809
Less: Oregon Portion 47,705 $1,205,017 $1,405,853
Total 136,496 $3,447,826 $3,773,956
Annualized Therms
GJ to Dth Conversion Factor 1.055056
Dth Per Day 144,011
Days 365
WA/ID Annualized Therms 52,564,015
Note I * FT Firm Service Rate, effective January 1, 2012 (Canadian cents/Gj/Km/Month)
Page 11
Avista Utilities
State of Idaho
TCPL BC (NOVA) Demand Calculation
Annual 13 Month
change Mileage Mileage Annual 13 Month
Rate Costs Costs Contract Contract
In U.S. In U.S. Demand (Dth) Demand (Dth)
Dollars Dollars
100% $64,090 $69,431 372,592 403,641
100% $1,022,052 $1,107,223 5,941,746 6,436,892
100% $760,574 $823,955 4,421,628 4,790,097
100% $908,451 $984,155 5,281,322 5,721,432
100% $418,521 $453,398 2,433,089 2,635,846
100% $63,436 $68,722 368,786 399,518
100% $3,654,395 $3,958,928 21,244,986 23,015,402
100% $326,283 $353,473 1,896,861 2,054,933
100% $1,143,967 $1,601,554 4,762,473 5,714,968
$ 8,361,769 $ 9,420,839 46,723,483 51,172,729
$ 6,180,936 $ 6,963,790 34,537,531 37,826,369
$2,180,833 $2,457,049 12,185,952 13,346,360
$ 8,361,769 $ 9,420,839 46,723,483 51,172,729
Annual
Contract No. Annual Monthly Monthly Mileage
Contract No. Demand of Contract Mileage Mileage Costs
(Gj) Days Demand (GJ) Rate Rate In Canadian
(Note 1) Dollars
2010-445837 (Firm) 1,077 365 393,105 $4.959 $0163036 $64,090
2010-445834 (Firm) 17,175 365 6,268,875 $4.959 $0163036 $1,022,052
2010-445835 (Firm) 12,781 365 4,665,065 $4.959 $0.163036 $760,574
2010-445836 (Firm) 15,266 365 5,572,090 $4.959 $0.163036 $908,451
2010-445836 (Firm) 7,033 365 2,567,045 $4.959 $0.163036 $418,521
2010-447082 (Firm) 1,066 365 389,090 $4.959 $0.163036 $63,436
2010-447082 (Firm) 61,410 365 22,414,650 $4959 $0.163036 $3,654,395
2010-447082 (Firm) 5,483 365 2,001,295 $4.959 $0.163036 $326,283
2006-245371 (Firm) 33,276 151 5,024,676 $6.876 $0.226050 $1,143,967
49,295,891 $ 8,361,769
Washington/Idaho Portion
Oregon Portion
Note 1 - Rate Schedule FT-D expressed in GJ, effective 1/1/11
Page 12
Avista Utilities
State of Idaho
Westcoast Energy - Demand Calculation
Rate Schedule FT-D, Appendix A, Effective 4/1/12
Demand Rate per month (C$)
(10 cubed/rn cubed)
Daily Demand (*12 mos1365 days)
Convert to GJ (/38.25)
Convert to MMBtu's (*1 .055056)
Convert to U.S. Dollars
Billing Determinants
Contract Demand E3M3
Number of Days
Annual Contract Demand E3M3
Conversion Factor
GJ
Conversion Factor
Dth
Total Annual Costs
Washington/Idaho Percentage
Washington/Idaho Portion
Total 13 Months Costs (Annual Costs / 12Mos * 13Mos)
$459.64
$15.1115
$0.395071
$0.416822
100%
$0.416822
272.0
365
99,280.0
38.25
3,797,460
1.055056
3,599,297
$1,500,266
81%
$1,215,215
$1,316,483
Page 13
Avista Utilities
State of Idaho
Budget Information - Therms
Rate Sch. Oct-12 Nov-12 Dec-12 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Total
101 3,237302 6,899,109 9,523,289 9160,047 7,251,059 6,517,822 4,303,468 2,416141 1,299,247 1,104,470 1,051,995 1,313,764 3,273,833 57,351,546
111 2,173,122 2,551,190 2,857,723 2,631,003 2,198,156 1,781,799 1,467,584 1,003,118 890,546 957,124 1,007,364 1,175,096 2,206,509 22,900,334
132 52,600 59,154 50,643 44,139 38,289 36,904 31,349 26,795 19,856 25,297 26,537 28,865 53,437 493,865
Total Sales 5,463,024 9,509,453 12,431,655 11,835,189 9,487,504 8,336,525 5,802,401 3,446,054 2,209,649 2,086,891 2,085,896 2,517,725 5,533,779 80,745,745
Page 14
Avista Utilities
State of Idaho
Recap of Changes To Schedule 150/156
Anticipated Effect Date 10/1/12
CENTS PER THERM
Schedule 101
Current Rate
Proposed lncr<Decr>
Proposed Rate
Schedule 111
Current Rate
Proposed lncr<Decr>
Proposed Rate
Schedule 112
Current Rate
Proposed Incr<Decr>
Proposed Rate
Schedule 131
Current Rate
Proposed lncr<Decr>
Proposed Rate
Schedule 132
Current Rate
Proposed lncr<Decr>
Proposed Rate
Schedule 146
Current Rate
Proposed lncr<Decr>
Proposed Rate
Commodity Demand Charge Total
0.36216 0.11176 0.47392
(0.02931) (0.00849) (0.03780)
0.33285 0.10327 0.43612
0.36216 0.11176 0.47392
(0.02931) (0.00849) (0.03780)
0.33285 0.10327 0.43612
0.36216 0.11176 0.47392
(0.02931) (0.00849) (0.03780)
0.33285 0.10327 0.43612
0.36216 0.36216
(0.02931) (0.02931)
0.33285 0.33285
0.36216 0.36216
(0.02931) (0.02931)
0.33285 0.33285
Page 15
Avista Utilities
State of Idaho
Calculation of Changes to Schedule 155
Current Proposed Total
Rate Rate Proposed
lncr <Decr> lncr <Decr> lncr <Decr>
Firm Customers, Schs 101 & 111
Firm Customers, Schedules 112
Interruptible Customers, Schedules 131
Interruptible Customers, Schedules 132
Transportation Customers, Schedules 146

($002885) ($003775) ($000890)

($003314) ($003517) ($000203)
Page 16
Avista Utilities
Idaho Gas Tracker
Calculation of New Amortization Rate
Schedule 155
Amortization Total
All Firm All Sales Rate Revenue Amortization
Customers Customers Before GRF Adjustment Rate
Schedule 101 ($0.00257) ($0.03504) ($0.03761) ($0.00014) ($003775)
Schedule 111 ($000257) ($0.03504) ($003761) ($0.00014) ($003775)
Schedule 112
Schedule 131 ($003504) ($0.03504) ($0.00013) ($0.03517)
Schedule 132
Page 17
Avista Utilities
Idaho Gas Tracker
Balances at 6/30/12
Unamortized Current
Deferrals Deferrals Total Adjustments Total
(Acct 191000) (Acct 191010) (Note 1)
All Firm Customers 1,363,736.02 (1,568,952.54) (205,216.52) (205,216.52)
All Sales Customers (718,714.72) (2,074,598.06) (2,793,312.78) (6,164.83) (2,799,477.61)
Customer 1 (9,750.08) (13,227.60) (22,977.68) (22,977.68)
Customer 2 (0.31) (385.36) (385.67) (385.67)
Customer 3
Customer 4 (1,915.05) (1,915.05) (1,915.05)
Customer (9,576.36) (13,012.96) (22589.32) (22,589.32)
625,694.55 (3,672,091.57) (3,046,397.02) (6,164.83) (3,052,561.85)
Note 1 - Balance in Account 254335, Idaho DSIT Amortization, as of 6/30/12
Page 18
Avista Utilities
Idaho Gas Tracker
Calculation of Amortization Rate
Firm Customers (Schedules 101 & 111)
Estimated Estimated Total Balance
Sch 101 Sch 111 Estimated Amortization Interest To Be
Therms Therms Therms ($0.00257) 1.00% Amortized
($205,216.52)
(191,476.95)
(167,339.12)
(135,646.11)
(105,443.52)
(81,236.79)
(59,965.57)
(45,177.76)
(36,424.25)
(30,824.49)
(25,549.67)
(20,276.21)
(13,894.07)
184.70
October 2012 3,237,302 2,173,122 5,410,424 $13,904.79 ($165.22)
November 6,899,109 2,551,190 9,450,299 24,287.27 (149.44)
December 9,523,289 2,857,723 12,381,012 31,819.20 (126.19)
January 2013 9,160,047 2,631,003 11,791,050 30,303.00 (100.41)
February 7,251,059 2,198,156 9,449,215 24,284.48 (77.75)
March 6,517,822 1,781,799 8,299,621 21,330.03 (58.81)
April 4,303,468 1,467,584 5,771,052 14,831.60 (43.79)
May 2,416,141 1,003,118 3,419,259 8,787.50 (33.99)
June 1,299,247 890,546 2,189,793 5,627.77 (28.01)
July 1,104,470 957,124 2,061,594 5,298.30 (23.48)
August 1,051,995 1,007,364 2,059,359 5,292.55 (19.09)
September 1,313,764 1,175,096 2,488,860 6,396.37 (14.23)
October 2013 3,273,833 2,206,509 5,480,342 14,084.48 (5.71)
57,351,546 22,900,334 80,251,880 $206,247.34 ($846.12)
Page 19
Avista Utilities
Idaho Gas Tracker
Calculation of Amortization Rate
Sales Customers (Schedules 101,111 & 131)
Estimated Estimated Estimated Total Balance
Sch 101 Sch 111 Sch 131 Estimated Amortization Interest To Be
Therms Therms Therms Therms ($003504) 1.00% Amortized
($2,799,477.61)
October 2012 3,237,302 2,173,122 5,410,424 $189,581.26 ($2,253.91) (2,612,150.26)
November 6,899,109 2,551,190 9,450,299 331,138.48 (2,038.82) (2,283,050.60)
December 9,523,289 2,857,723 12,381,012 433,830.66 (1,721.78) (1,850,941.72)
January 2013 9,160,047 2,631,003 11,791,050 413,158.39 (1,370.30) (1,439,153.63)
February 7,251,059 2,198,156 9,449,215 331,100.49 (1,061.34) (1,109,114.48)
March 6,517,822 1,781,799 8,299,621 290,818.72 (803.09) (819,098.85)
April 4,303,468 1,467,584 5,771,052 202,217.66 (598.33) (617,479.52)
May 2,416,141 1,003,118 3,419,259 119,810.84 (464.65) (498,133.33)
June 1,299,247 890,546 2,189,793 76,730.35 (383.14) (421,786.12)
July 1,104,470 957,124 2,061,594 72,238.25 (321.39) (349,869.26)
August 1,051,995 1,007,364 2,059,359 72,159.94 (261.49) (277,970.81)
September 1,313,764 1,175,096 2,488,860 87,209.65 (195.30) (190,956.46)
October 2013 3,273,833 2,206,509 5,480,342 192,031.18 (79.12) 995.60
57,351,546 22,900,334 80,251,880 $2,812,025.87 ($11,552.66)
Page 20
Avista Utilities
Idaho Gas Tracker
Revenue Adjustment Factor
From General Rate Case AVU-G-1 1-01, Filed 7/05/11
Commission Fees $0.002039
Uncollectibles $0.001665
$0.003704
Calculation of Revenue Adjustment Factor
11(1 - 0 )= 1.003718
Page 21
Avista Utilities
State of Idaho
Account 191000 Detail
6/30/11 7/31/11 7/31/1I 7/31/11 8/31/11 8/31/11 8/31/11
Balance Amortization Interest Balance Amortization Interest Balance
Firm Customers 1,779,700.67 (10,417.53) 1,478.74 1,770,761.88 (9,278.39) 1,471.77 1,762,955.26
All Sales Customers (2,480,406.48) 165,548.19 - (1,998.02) (2,316,856.31) 147445.65 (1,869.28) (2,171,279.94)
Customer 1 (57,503.42) (47.92) (57,551.34) (47.96) (57,599.30)
- Customer 2 (22.44) (0.02) (22.46) (0.02) (22.48)
Customer 3 (3,437.77) (2.86) (3,440.63) (2.87) (3,443.50)
- Customer 4
Customer (37,087.85) (30.91) (37,118.76) (30.93) (37,149.69)
Total (798,757.29) 155,130.66 1 (600.99) (644,227.62) 138,167.26 (479.29) (506,539.65)
Page 22
Avista Utilities
State of Idaho
Account 191000 Detail
9/30/11 9/30/11 9/30/11 PGA 10/31/11 10/31/11
Amortization Interest Balance Transfer Amortization Interest Balance
Firm Customers (10,390.94) 1,464.80 1,754,029.12 (109,606.78) (23,063.51) 1,360.74 1,622,719.57
All Sates Customers - 165,125.63 (1,740.59) (2,007,894.90) (947,467.17) 174,71296 (2,400.04) (2,783,049.15)
Customer 1 (48.00) (57,647.30) (10,477.69) (56.77) (68,181.76)
Customer 2 (0.02) (22.50) (78.58) 100.81 (0.04) (0.31)
Customer 3 (2.87) (3,446.37) 3,437.77 8.60
Customer 4
- Customer (30.96) (37,180.65) (11,317.96) 39,010.01 (24.16) (9,512.76)
Total 154,734.69 1 (357.64) (352,162.60) (1,078,948.18) 194,198.04 1 (1,111.67) (1,238,024.41)
Page 23
Avista Utilities
State of Idaho
Account 191000 Detail
11/30/11 11/30/11 12/31/11 12/31/11 1/31/12
Amortization Interest Balance Amortization Interest Balance Amortization Interest
Firm Customers (41,322.54) 1,335.05 1,582,732.08 (53,049.55) 1,296.84 1,530,979.37 (49,171.09) 1,255.33
All Sales Customers - 319,856.12 (2,185.44) (2,465,378.47) 409,366.44 (1,883.92) (2,057,895.95) 379,389.69 (1,556.84)
Customer 1 58,520.79 (32.43) (9,693.40) (8.08) (9,701.48) (8.08)
Customer 2 (0.31) (0.31)
- Customer 3
Customer 4
Customer 5 (7.93) (9,520.69) (7.93) (9,528.62) (7.94)
Total 337,054.37 1 (890.75) (901,860.79)1 356,316.89 1 (603.09) (546,146.99)1 330,218.60 1 (317.53)
Page 24
Avista Utilities
State of Idaho
Account 191000 Detail
1/31/12 2/29/12 2/29/12 2/29/12 3/31/12 3/31/12 3/31/12 4/30/12
Balance Amortization Interest Balance Amortization Interest Balance Amortization
Firm Customers 1,483,063.61 (40,774.46) 1,218.90 1,443,508.05 (36,497.69) 1,187.72 1,408,198.08 (21,501.42)
All Sales Customers - (1,680,063.10) 314,573.05 (1,26898) (1,366,759.03) 281,578.01 (1,021.65) (1,086,202.67) 165,882.41
Customer 1 (9,709.56) (8.09) (9,717.65) (8.10) (9,725.75) _
Customer 2 (0.31) (0.31) (0.31)
Customer 3
- Customer 4
- Customer 5 (9,536.56) (7.95) (9,544.51) (7.95) (9,552.46)
Total (216,245.92) 273,798.59 (66.12)1 57,486.55 1 245,080.32 1 150.02 1 302,716.89 1 144,380.99
Page 25
Avista Utilities
State of Idaho
Account 191000 Detail
4/30/12 4/30/12 5/31/12 5/31/12 5/31/12 6/30/12 6/30/12 6/30/12
Interest Balance Amortization Interest Balance Amortization Interest Balance
Firm Customers 1,164.54 1,387,861.20 (14,661.38) 1,150.44 1,374,350.26 (11,754.63) 1,140.39 1,363,736.02
All Sales Customers - (836.06) (921,156.32) 113,111.83 (720.50) (808,764.99) 90,686.45 (636.18) (718,714.72)
Customer 1 (8.10) (9,733.85) (8.11) (9,741.96) (8.12) (9,750.08)
- Customer 2 (0.31) (0.31) (0.31)
- Customer 3
Customer 4
- Customer 5 (7.96) (9,560.42) (7.97) (9,568.39) _______ (7.97) (9,576.36)
Total 312.42 447,410.30 98,450.45 413.86 546,274.61 78,931.82 488.12 625,694.55
Page 26
Avista Utilities
State of Idaho
Recap of Acct 191010
Balance 7/311I1 Demand & Interest Balance 8/31/11 Demand & Interest
6/30/11 Commodity Capacity Rel. 7/31/11 Commodity Capacity Rel.
Deferral Deferrals Deferral Deferrals
Customer 1 (1,017.37) (3,903.15) 1,711.60 (1.76) (3,210.68) (6,708.19) 1,708.79 (4.76)
Customer 2 - (78.37) (0.07) (78.44) (0.07)
- Customer 3
Customer 4
Customer 5 - (1,922.16) (2,207.97) (2.52) (4,132.65) (3,462.61) (4.89)
Firm Customers (1,439,952.56) 425,576.42 (1,022.62) (1,015,398.76) 476,992.83 (647.42)
Sales Customers (141,932.88) (219,886.36) (209.90) (362,029.14) (275,045.81) (416.29)
- (1,584,903.34) (225,997.48) 427,288.02 (1,236.87) 1,384,849.67) (1,384,849.67)11 (285,216.61)1 478,701.62 1 (1,073.43)
OK OK
Page 27
Avista Utilities
State of Idaho
Recap of Acct 191010
Balance 9/30/11 Demand & Interest Balance PGA 10/31/11 Demand &
8/31/11 Commodity Capacity Rel. 9/30/11 Transfer Commodity Capacity Rel.
Deferral Deferrals Deferral Deferrals
Customer 1 (8,214.84) (3,737.58) 1,482.52 (7.79) (10,477.69) 10,477.69 (1,738.58) (107.41)
Customer 2 - (78.51) (0.07) (78.58) 78.58
Customer 3
Customer 4
Customer - (7,600.15) (3,709.93) (7.88) (11,317.96) 11,317.96 (2,451.72)
Firm Customers (539,053.35) 429,716.73 (270.16) (109,606.78) 109,606.78 (35,706.78)
Sales Customers (637,491.24) (309,315.80) (660.12) (947,467.16) 947,467.17 (257,684.09)
- (1,192,438.09) (316,763.31) 431,199.25 (946.02) (1,078,948.17) 1,078,948.18 (261,874.39) (35,814.19)
OK OK
Page 28
Avista Utilities
State of Idaho
Recap of Acct 191010
Interest Balance 11/30/11 Demand & Interest Balance 12/31/11 Demand & Interest
10/31/11 Commodity Capacity Rel. 11/30/11 Commodity Capacity Rel.
Deferral Deferrals Deferral Deferrals
Customer 1 (0.77) (1,846.76) 122.75 (973.25) (1.89) (2,699.15) (2.25)
Customer - 1.80 (38.19) (0.02) (36.41) (133.59) (75.81) (0.12)
- Customer 3
Customer 4
Customer 5 (1.02) (2,452.74) 148.74 (1.98) (2,305.98) (2,405.73) (2.92)
Firm Customers (14.88) (35,721.66) (370,044.65) (183.95) (405,950.26) (659,671.76) (613.16)
Sales Customers (107.37) (257,791.45) 30,028.87 (202.31) (227,964.89) (639,388.70) (456.38)
- (124.04) (297,812.61) 30,302.16 (371,056.09) (390.15) (638,956.69) (641,928.02) 659,747.57) (659,747.57)11 (1,074.83)
OK OK __
Page 29
Avista Utilities
State of Idaho
Recap of Acct 191010
Balance 1/31/12 Demand & Interest Balance 2/29/12 Demand & Interest
12/31/11 Commodity Capacity Rel. 1/31/12 Commodity Capacity Rel.
Deferral Deferrals Deferral Deferrals
Customer 1 (2,701.40) (2.25) (2,703.65) (2.25)
Customer 2 - (245.93) (4.49) (64.55) (0.23) (315.20) 5.72 (29.05) (0.27)
- Customer 3
- Customer 4
Customer 5 (4,714.63) (221.09) (4.02) (4,939.74) 518.84 (3.90)
Firm Customers (1,066,235.18) (561,653.92) (1,122.55) (1,629,011.65) (357,731.58) (1,506.56)
Sales Customers (867,809.97) (53,835.96) (745.61) (922,391.54) 136,524.49 (711.77)
- (1,941,707.11) (54,061.54) (561,718.47) (1,874.66) (2,559,361.78) 137,049.05 (357,760.63) (2,224.75)
OF OK
Page 30
Avista Utilities
State of Idaho
Recap of Acct 191010
Balance 3/31/12 Demand & Interest Balance 4/30/12 Demand & Interest
2/29/12 Commodity Capacity Rel. 3/31/12 Commodity Capacity Rel.
Deferral Deferrals Deferral Deferrals
Customer 1 (2,705.90) (2.25) (2,708.15) (64.50) 178.04 (2.21)
Customer 2 - (338.80) (13.11) (14.83) (0.29) (367.03) (22.37) 4.99 (0.31)
- Customer 3
Customer 4
Customer 5 - (4,424.80) (577.76) (3.93) (5,006.49) (1,049.93) (4.61)
Firm Customers (1,988,249.79) (226,008.20) (1,751.05) (2,216,009.04) 65,482.02 (1,819.38)
Sales Customers (786,578.82) (146,256.17) (716.42) (933,551.41) (213,745.54) (867.02)
-
(2,782,298.11) (146,847.04) (226,023.03) (2,473.94) (3,157,642.12) (214,882.34) 65,665.05 (2,693.53)
OK OK
Page 31
Avista Utilities
State of Idaho
Recap of Acct 191010
Balance 5/31/12 Demand & Interest Balance 6/30/12 Demand & Interest Balance
4/30/12 Commodity Capacity Rel. 5/31/12 Commodity Capacity Rel. 6/30/12
Deferral Deferrals Deferral Deferrals
Customer 1 (2,596.82) (5,542.61) 867.00 (4.11) (7,276.54) (7,164.64) 1,222.12 (8.54) (13,227.60)
Customer 2 - (384.72) (0.32) (385.04) (0.32) (385.36)
- Customer 3
Customer (1,449.06) 62.89 (0.58) (1,386.75) (526.92) (1.38) (1,915.05)
Customer 5 (6,061.03) (2,340.21) (6.03) (8,407.27) (4,596.77) (8.92) (13,012.96)
Firm Customers (2,152,346.40) 250,148.70 (1,689.38) (1,903,887.08) 336,380.94 (1,446.40) (1,568,952.54)
Sales Customers (1,148,163.97) (358,870.19) (1,106.33) (1,508,140.49) (564,965.38) (1,492.19) (2,074,598.06)
- (3,309,552.94) (368,202.07)1 251,078.59 1 (2,806.75) (3,429,483.17) (577,253.71) 337,603.06 (2,957.75) (3,672,091.57)
OK OK OK
Page 32
Washington Water Power Company
State of Idaho
Analysis of Account 191010
Demand &
Total Commodity Cap. Rel. Interest
Acct 191010 Deferral Deferral
6/30/11 Ending Balance (1,584,903.34) (145,966.85) (1,432, 158.55) (6,777.94)
7/31/11 Current Deferrals 201,290.54 (225,997.48) 427,288.02
Estimated Interest (1,236.87) (1,236.87)
7/31/11 Ending Balance (1,384,849.67) (371,964.33) (1,004,870.53) (8,014.81)
8/31/11 Current Deferrals 193,485.01 (285,216.61) 478,701.62
Estimated Interest (1,073.43) (1,073.43)
8/31/11 Ending Balance (1,192,438.09) (657,180.94) (526,168.91) (9,088.24)
9/30/11 Current Deferrals 114,435.94 (316,763.31) 431,199.25
Estimated Interest (946.02) (946.02)
9/30/11 Ending Balance (1,078,948.17) (973,944.25) (94,969.66) (10,034.26)
10/31/11 Current Deferrals (297,688.58) (261,874.39) (35,814.19)
PGA Transfer 1,078,948.18 973,944.25 94,969.66 10,034.27
Estimated Interest (124.04) (124.04)
10/31/11 Ending Balance (297,812.61) (261,874.39) (35,814.19) (124.03)
11/30/11 Current Deferrals (340,753.93) 30,302.16 (371,056.09)
Estimated Interest (390.15) (390.15)
11/30/11 Ending Balance (638,956.69) (231,572.23) (406,870.28) (514.18)
12/31/11 Current Deferrals (1,301,675.59) (641,928.02) (659,747.57)
Estimated Interest (1,074.83) (1,074.83)
12/31/11 Ending Balance (1,941,707.11) (873,500.25) (1,066,617.85) (1,589.01)
1/31/12 Current Deferrals (615,780.01) (54,061.54) (561,718.47)
Estimated Interest (1,874.66) (1,874.66)
1/31/12 Ending Balance (2,559,361.78) (927,561.79) (1,628,336.32) (3,463.67)
2/29/12 Current Deferrals (220,711.58) 137,049.05 (357,760.63)
Estimated Interest (2,224.75) (2,224.75)
2/29/12 Ending Balance (2,782,298.11) (790,512.74) (1,986,096.95) (5,688.42)
3/31/12 Current Deferrals (372,870.07) (146,847.04) (226,023.03)
Estimated Interest (2,473.94) (2,473.94)
3/31/12 Ending Balance (3,157,642.12) (937,359.78) (2,212,119.98) (8,162.36)
4/30/12 Current Deferrals (149,217.29) (214,882.34) 65,665.05
Estimated Interest (2,693.53) (2,693.53)
4/30/12 Ending Balance (3,309,552.94) (1,152,242.12) (2,146,454.93) (10,855.89)
5/31/12 Current Deferrals (117,123.48) (368,202.07) 251,078.59
Estimated Interest (2,806.75) (2,806.75)
Page 33
Washington Water Power Company
State of Idaho
Analysis of Account 191010
Demand &
Total Commodity Cap. Rel. Interest
Acct 191010 Deferral Deferral
5/31/12 Ending Balance (3,429,483.17) (1,520,444.19) (1,895,376.34) (13,662.64)
6/30/12 Current Deferrals (239,650.65) (577,253.71) 337,603.06
Estimated Interest (2,957.75) (2,957.75)
6/30/12 Ending Balance (3,672,091.57) (2,097,697.90) (1,557,773.28) (16,620.39)
Page 34
AVISTA UTILITIES
Case No. AVU-G-12-0 ,~
EXHIBIT "D"
Pipeline Tariffs
July 30, 2012
FERC Gas Tariff Third Revised Sheet No. 5
Fifth Revised Volume No. 1 Superseding
Second Revised Sheet No. 5
Currently
Base Effective
Rate Schedule and Tariff Rate Tariff Rate(3)
Type of Rate Minimum Maximum ACA(2) Minimum Maximum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide .00000 .37883 - .00000 .37883
15 Year Evergreen Exp. .00000 .37995 - .00000 .37995
25 Year Evergreen Exp. .00000 .36344 - .00000 .36344
Volumetric
(Large Customer)
System-Wide .00756 .03000 .00180 .00936 CO3:18~0)
15 Year Evergreen Exp. .00369 .00369 .00180 .00549 .00549
25 Year Evergreen Exp. .00369 .00369 .00180 .00549 .00549
(Small Customer) (6) .00756 .67209 .00180 .00936 .67389
Scheduled Overrun .00756 .40984 .00180 .00936 .41164
Rate Schedule TF-2 (4) (5)
Reservation .00000 .37883 - .00000
Volumetric .00756 .03000 - .00756 O 3000T)
Scheduled Daily Overrun .00756 .40984 - .00756 .40984
Annual Overrun .00756 .40984 - .00756 .40984
Rate Schedule TI-1
Volumetric (7) .00756 .40984 .00180 .00936 .41164
Rate Schedule TFL-1 (4) (5)
Reservation - - - - -
Volumetric - - - - -
Scheduled Overrun - - - - -
Rate Schedule TIL-1
Volumetric - - - - -
Northwest Pipeline GP
FERC Gas Tariff Pro Forma Sheet No. 5
Fifth Revised Volume No. 1
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1
(Dollars per Dth)
Currently
Base Effective
Rate Schedule and Tariff Rate Tariff Rate(3)
Type of Rate Minimum Maximum ACA(2) Minimum Maximum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide .00000 .37883 - .00000
.41000
c410_'
15 Year Evergreen Exp. .00000 .-37995 - .00000 .37995
.36263 .36263
25 Year Evergreen Exp. .00000 .36344 - .00000 .36341
.34234 .34234
Volumetric
(Large Customer)
System-Wide .00756 .03000 .00180 .00936 (.03180.
.00813 .00993 '---------
15 Year Evergreen Exp. .0039 .00369 .00180 .00549 .00E49
.00813 .00813 .00993 .00993
25 Year Evergreen Exp. .00369 .00369 .00180 .0-0549 .00519
.00813 .00813 .00993 .00993
(Small Customer) (6) .00756 .67209 .00180 .0-0936 .67339
.00813 .72155 .00993 .72335
Scheduled Overrun .0-0756 .40984 .00180 .00936 .41164
.00813 .44000 .00993 .44180
Rate Schedule TF-2 (4) (5)
Reservation .00000 .37883 - .00000 .37383
41000 41000
Volumetric .00756 .03000 - .00756 C.~300 0 1 .00813 .00813
Scheduled Daily Overrun .00756 .40981 - .00756 .40984
.00813 .44000 .00813 .44000
Annual Overrun .00756 .40984 - .00756 .40984
.00813 .44000 .00813 .44000
Rate Schedule TI-1
Volumetric (7)
Rate Schedule TFL-1 (4) (5)
Reservation
Volumetric
Scheduled Overrun
Rate Schedule TIL-1
Volumetric

.00756 .40984 .00180 .00936 .11164

.00813 .44000 .00993 .44180
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 - Statement of Rates
Fourth Revised Volume No. 1-A FTS- I and LFS- 1 Rates
v.7.0.0 Superseding v.6.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1 and LFS-1
RESERVATION
DAILY DAILY
MILEAGE (a) NON-MILEAGE (b) DELIVERY (c) FUEL (d)
(Dth-MILE) (Dth) (Dth-MILE) (Dth-MILE)
Max. Mm. Max. Mm. Max. Mm. Max. Mm.
BASE 016 0.000016 0.0050% 0.0000%
STF (e) (e) 0.000000 (e) 0.000000 0.0000 16 0.0000 16 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-1 (f) 0.003290 0.000000 0.005498 0.000000 0.000026 0.000026
E-2 (g)(1) 0.009363 0.000000 --- --- 0.000000 0.000000
(WWP)
E-2 (h)(1) 0.002964 0.000000 --- --- 0.000000 0.000000
(Diamond 1)
E-2(h)(1) 0.001163 0.000000 --- --- 0.000000 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001412 0.000000 0.001420 0.000000 0.000000 0.000000 ---
OVERRUN CHARGE (3)
SURCHARGES
ACA (k) --- --- --- --- 0.001800 0.001800 ---
Issued: January 11, 2012 Docket No. RPI2-301-000
Effective: January 1, 2012 Accepted: February 7, 2012
FT-D Demand Rate 0 yr term) 2
Group 1:
Empress/McNeill Border
Alberta-B.C. Border
Gordondale Border/Boundary Lk Border
ATCO: Clairmont/Shell Creek/Edson
5.30/mo 17.4 18.6 17.8
18.1 19.3 18.5
3.44/mo 11.3 12.1 11.5
2.391mo 7.8 8.4 8.0
Group 2:
ATCO North FSD points
ATCO South FSD points
Alberta Montana/Unity/Cold Lake
All other Group 2 delivery locations
3.39/mo 11.1 11.9 11.4
2.39/mo 7.8 8.4 8.0
3.44/mo 11.3 12.1 11.5
2.39/mo 7.8 8.4 8.0
Group 3:
ATCO North FSU points
ATCO South FSU points
All other Group 3 delivery locations
4.12/mo 13.5 14.5 13.8
2.87/mo 9.4 10.1 9.6
2.87/mo 9.4 10.1 9.6
Alberta System Page 1 of
TransCanada
In business to deliver
Alberta System
TransCanada's - Alberta System Transportation Rates
2012 Interim Rates Effective January 1, 2012
Receipt Services Tariff Rate Information Purposes
ELB Average Demand Rate (3 yr term)
IT-R (Interruptible Receipt)
$11 03M3 çUGJ!d UMcfId OIMMBtuld
(Cdn) (Cdn) (Cdn) (US)
179.94/mo 15.6 16.7 16.0
6.781d 17.9 19.2 18.3
Delivery Services Tariff Rate Information Purposes

$GJ çtlGJId çIMcfld lMMBtuld

(Cdn) (Cdn) (Cdn) (US)
http://www.transcanada.comlcustomerexpress/2766.html 7/19/2012
NOVA Gas Transmission Ltd. Attachment 2
Table of Rates, Tolls and Charges
Page 1 of
Group 1 FT-D Demand Rate IT-D Rate I
Delivery Point Group 1 Delivery Point Name per Month
Price Point "Z" per Day
Number ($FGJ)
2000 ALBERTA-B.C. BORDER c.51) 0.1986
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 2.39 0.0861
31110 ALLIANCE EDSON INTERCONNECT APN 2.39 0.0861
31112 ALLIANCE SHELL CREEK INTERCONNECT APGC 2.39 0.0861
3002 BOUNDARY LAKE BORDER 3.44 0.1242
1958 EMPRESS BORDER 5.30 0.1911
3886 GORDONDALE BORDER 3.44 0.1242
6404 MCNEILL BORDER 5.30 0.1911
Group 2 FT-D Demand Rate IT-D Rate :
Delivery Point Group 2 Delivery Point Name per Month
Price Point "Z" per Day
ISubjecttoATC0
Pipelines
Number ($IGJ) ($/GJ) Franchise Fees'
31000 A.T. PLASTICS SALES APN 3.39 0.1226 Yes
31001 ADM AGRI INDUSTRIES SALES APN 3.39 0.1226 Yes
3880 AECO INTERCONNECTION 2.39 0.0861
31003 AGRIUM CARSELAND SALES APS 2.39 0.0861
31002 AGRIUM FT. SASK SALES APN 2.39 0.0861 Yes
31004 AGRIUM REDWATER SALES APN 2.39 0.0861
31005 AINSWORTH SALES APGP 3.39 0.1226
31006 AIR LIQUIDE SALES APN 3.39 0.1226
3214 AKUINU RIVER WEST SALES 2.39 0.0861
31007 ALBERTA ENVIROFUELS SALES APN 3.39 0.1226 Yes2
31008 ALBERTA HOSPITAL SALES APN 3.39 0.1226 Yes
3868 ALBERTA-MONTANA 3.44 0.1242
3059 ALLISON CREEK SALES 2.39 0.0861
31009 ALTASTEEL SALES APN 3.39 0.1226 Yes2
3562 AMOCO SALES (BP SALES TAP) 2.39 0.0861
31012 APL JASPER SALES APN 3.39 0.1226 Yes
3488 ARDLEY SALES 2.39 0.0861
3216 AURORA NO 2 SALES 2.39 0.0861
3135 AURORA SALES 2.39 0.0861
3423 BASHAW WEST SALES 2.39 0.0861
31013 BAYMAG SALES APS 2.39 0.0861
31014 BEAR CREEK COGEN SALES APGP 3.39 0.1226
3068 BEAVER HILLS SALES 2.39 0.0861
3933 BIG EDDY INTERCONNECTION 2.39 0.0861
3067 BIGSTONE SALES 2.39 0.0861
3468 BLEAK LAKE SALES 2.39 0.0861
3164 BRAINARD LAKE SALES 2.39 0.0861
3918 BUFFALO CREEK INTERCONNECTION 2.39 0.0861
31015 BURDETTCOGEN SALES APS 2.39 0.0861
3204 CABIN SALES 2.39 0.0861
3109 CALDWELL SALES 2.39 0.0861
31016 CALGARY ENERGY CENTRE SALES APS 2.39 0.0861 Yes
3634 CANOE LAKE SALES 2.39 0.0861
3165 CANOE LK SLS #2 2.39 0.0861
3866 CARBON INTERCONNECTION 2.39 0.0861
3484 CARIBOU LAKE SALES 2.39 0.0861
3157 CARIBOU LK SOUTH SL 2.39 0.0861
3106 CARMON CREEK SALES 2.39 0.0861
3101 CAROLINE SALES 2.39 0.0861
31017 CARSELAND COGEN SALES APS 2.39 0.0861
3495 CAVALIER SALES 2.39 0.0861
31018 CHAIN LAKES COOP SALES APS 2.39 0.0861
3907 CHANCELLOR INTERCONNECTION 2.39 0.0861
3151 CHEECHAM W. #2 SALES 2.39 0.0861
3622 CHEECHAM WEST SALES 2.39 0.0861
6014 CHEVRON AURORA SALES 2.39 0.0861
31019 CHEVRON FT. SASK SALES APN 3.39 0.1226 Yes
TARIFF Effective: January 1, 2012 (Amended June 1, 2012)
Page 8.4
Westcoast Energy Inc.
TOLL SCHEDULES - SERVICE
APPENDIX A
DEMAND AND COMMODITY TOLLS
TRANSPORTATION SERVICE - SOUTHERN
Firm Transportation Service - Southern
Demand Toils $/103M3/Mo.
Terasen
PNG Inland Huntingdon Kingsvale to
Service Term Delivery Point Delivery Area Delivery Area* Huntingdon-
1 year 112.90 295.90 498.35 202.45
2 years 109.61 287.26 483.83 196.55
3 years 106.32 278.66 469.32 190.65
4 years 105.23 275.79 464.48 188.69
5 years or more 104.13 272.92 459.64 186.72
* To be increased to the percentage amount of the applicable toll specified in a Service Agreement for
Enhanced T-South Service
** For Firm Transportation Service - Southern provided by Westcoast pursuant to a Firm Service Agreement
dated April 15, 2002 between Westcoast and Terasen Gas Inc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for eachday in the month.
AOS and Interruptible Transportation Service - Southern
Commodity Tolls
$11 03m3
Terasen

PNG Inland Huntingdon Kingsvale to
Months Delivery Point Delivery Area Delivery Area Huntingdon*
November to March 4.927 12.912 21.747 8.835
April to October 3.695 9.684 16.310 6.626
* For AOS provided by Westcoast pursuant to a Firm Service Agreement dated April 15, 2002 between
Westcoast and Terasen Gas Inc.
Plus the amount of tax on fuel gas consumed in operations payable under the Motor Fuel Tax Act
(British Columbia) and the Carbon Tax Act (British Columbia) which is allocated to Shipper by
Westcoast for each day in the month.
Effective Date: April 1, 2012
Foothills Pipe Lines Ltd. Page 1
TABLE OF EFFECTIVE RATES
1.Rate Schedule FT, Firm Transportation Service
Demand Rate
($/GJ/Km/Month)
Zone 6 0.0067657 123
Zone 7 0.0062022433
Zone 9 0.0090496758
2.Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone 6 0.0002440093
Zone 7 0.0002236875
3.Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
Zone 8* 0.0006044351
Zone 9 0.0003263818
* For Zone 8, Shippers Haul Distance shall be 170.7 km.
TARIFF - PHASE I Effective Date: January 1, 2012