20110815Application.pdf

Avista Corp. C E !
1411 East Mission P.O. Box 3727
Spokane. Washington 99220-050020 I! AUG I 5
Telephone [phone]
Toll Free 800-727-9170
Iii t Ji~'V'STA.
Corp.Ar1 9: 27
I:)
August 12,2011
State of Idaho
Idaho Public Utilties Commission
Statehouse
Boise, Idaho 83720
Case No. AVU-G-II-04/Advice No. 11-03-G
Attention: Ms. Jean D. Jewell
I.P.V.C. No. 27 - Natural Gas Service
Enclosed for filing with the Commission are the following revised tarff sheets:
Sixteenth Revision Sheet 150
Thirteenth Revision Sheet 155
canceling
canceling
Fifteenth Revision Sheet 150
Twelfth Revision Sheet 155
The Company requests that the proposed taff sheets be made effective October 1, 2011. These
taiff sheets reflect the Company's anual Purchased Gas Adjustment (PGA). If these taiff
sheets are approved as fied, the Company's anual revenue will increase by approximately $1.1
millon or about 1.53%. The proposed changes have no effect on the Company's net income.
The proposed increase results is caused by the elimination of a present refund to pass though gas
cost savings from prior years. Furher information is included in the attached Application and
supporting workpapers. If approved, the average residential or small commercial customer using
62 therms per month will see an increase of $0.99 per month, or approximately 1.63%. The
present bil for 62 therms is $60.76 while the proposed bil is $61.75.
If you have any questions regarding ths filing, please contact Patrick Ehrbar at [phone]
or Craig Bertolf at [phone].
Sincerely,~ ~~i.
Kelly Norwood
Vice President, State and Federal Regulation
Enclosures
10,l'\"lì$""ß
2lHI AUG 'SAM 9= 27
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that I have served Avista Corporation dba Avista Utilties' filing AVU-
G-11-04 with Tariff IPUC No. 27 Natural Gas Service by mailing a copy thereof, postage
prepaid to the following:
Jean D Jewell, Secretary
Idaho Public Utilties Commission
472 W. Washington Street
Boise, ID 83720-5983
Chad Stokes
Cable Huston Benedict Haagensen &
Lloyd, LLP
1001 SW 5th, Suite 2000
Portland, OR 97204-1136
Paula Pyron
Northwest Industrial Gas Users
4113 Wolfberry Court
Lake Oswego, OR 97035-1827
Curt Hibbard
St. Joseph Regional Medical Center
PO Box 816
Lewiston, ID 83501
g~ton this 12th day of August 2011.
Patrick Ehrbar
State & Federal Regulation
IN TH MATTER OF THE APPLICATION OF )
AVISTA UTILITllS FOR AN ORDER APPROVING )
A CHANGE IN NATU GAS RATES AN CHAGES )
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
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Vi i., If) i': , , 4¡4 l'.J -A . .. r"" ¡¡-¡-..~ :;.CASE: A VU-G-ii-dWt/l:r,v 27'-'0
Application is hereby made to the Idaho Public Utilties 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, 2011. If approved as filed, the Company's anual revenue wil increase by approximately $1.1
milion or about 1.53%. In support of this Application, Applicant states as follows:
I.
The name of the Applicant is AVISTA UTILITllS, 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 distrct offices in
Moscow, Lewiston, Coeur d'Alene, and Kellogg, Idaho. Communications in reference to this Application
should be addressed to:
Kelly O. Norwood
Vice President - State & Federal Regulation
A vista Utilities
P.O. Box 3727
Spokane, W A 99220-3727
II.
Attorney for the Applicant and his address is as follows:
David J. Meyer
Vice President and Chief Counsel for Regulatory &
Governental Affairs
Avista Utilties
P.O. Box 3727
Spokane, W A 99220-3727
III.
The Applicant is a public utilty engaged in the distrbution of natural gas in cerain portions of
Easter and Central Washington, Norther Idaho and Southwestern and Northeastern Oregon, and further
engaged in the generation, transmission, and distrbution of electrcity in Eastern Washington and
Northern Idaho.
IV.
Sixteenth Revision Sheet 150, which Applicant requests the Commission approve, is filed herewith
as Exhibit "A". Additionally, Thirteenth Revision Sheet 155, which Applicant requests the Commission
approve, is also fied herewith as Exhibit "A". Also included in Exhibit "A" is a copy of Sixteenth
Revision Sheet 150 and Thirteenth Revision Tariff Sheet 155 with the changes underlined and a copy of
Fifteenth Revision Sheet 150 and Twelfth Revision Tariff Sheet 155 with the proposed changes shown by
lining over the current language or amounts.
V.
The existing rates and charges for natual gas service on file with the Commission and designated
as Applicant's Tariff IPUC ~ö. 27, which wil be superseded by the rates and charges fied herewith, are
incorporated herein as thou~ 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 distrbuted to various informational
agencies, a copy attached hereto as Exhibit "E". In addition, a notice wil be sent to customers as a bil
insert prior to October 1, 2011, 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 natual gas for customer usage and transports it over Wiliams 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
(W ACOG) purchased and the W ACOG embedded in rates. Applicant also defers various pipeline refuds
or charges and miscellaneous revenue received from natual gas related transactions including pipeline
capacity releases.
IX.
This filing reflects the Company's proposed anual Purchased Gas Cost Adjustment (PGA) to: 1)
pass through changes in the estimated cost of natual gas for the forthcoming thirteen months (Schedule
150), and 2) revise the amortization rate(s) to refud 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 Sch. 155 Total Rate Overall
Sch.Change Change Sch. 150 Amort.Change Percent
Service No.pertherm perth Change per therm per therm Change
General 101 ($0.03796)$0.00690 ($0.03106)$0.04697 $0.01591 1.63%
Lg. General 111 ($0.03796)$0.00690 ($0.03106)$0.04697 $0.01591 2.05%
Interrptible 131 ($0.03796)$0.00000 ($0.03796)$0.04777 $0.00981 1.68%
X.
Commodity Costs
As shown in the table above, the estimated commodity cost (WACOG) change is a decrease of 3.8 cents
per thermo The proposed WACOG is 42.3 cents per therm compared to the present WACOG of 46.1 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 flexibilty 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 opportnities arse in the market.
Avista has been hedging gas on both a perodic and discretionar basis throughout 2011 for the
forthcoming PGA year (thirteen months). Approximately 70% of estimated anual load requirements for
the PGA year (October 2011 though October 2012) wil be hedged at a fixed price, comprised of: 1) 32%
of volumes hedged for a term of one year or less, 2) 18% of volumes from prior multi-year hedges, and 3)
20% of volumes from underground storage. Though July, the planed hedge volumes for the PGA year
have been executed at a weighted average price of$4.79 per dekatherm ($0.479 per ther).
The Company used a 30-day historical average of forward prices (ending July 29, 2011) 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 30% of estimated annual load requirements for the
coming year and the anual weighted average price for these volumes is $4.02 per dekather.
Available underground storage capacity at Jackson Prairie represents approximately 20% of annualloåd
requirements (31 % of load requirements durng the December to March withdrawal period). The
estimated weighted average cost for all storage volumes is $3.91 per dekatherm. The Company also
utilzes (optimizes) its underground storage capacity to provide additional benefits to customers beyond
the winter/summer price differential and supply reliabilty.
On average daily wholesale prices of natural gas have stayed at levels similar to 2010, However, the cash
prices experenced over the storage injection season (April - September) have been slightly higher than
2010. This increased pricing level has caused the storage W ACOG to be higher than what is currently in
rates. While cash prices are curently higher than levels experence a year ago, the forward prices for the
upcoming PGA year have continued to drop. This decline has provided the opportnity to hedge natural
gas at a cost below what is embedded in rates. The decrease in the cost of hedges more than offsets the
increase in the storage WACOG.
XI.
Demand Costs
The Demand Costs shown in the table above primarly represents the cost of pipeline transportation to the
Company's system. As shown in the table above, there is a slight increase which is due to, in part, a
proposed rate case settlement between Gas Transmission Northwest and their shippers (including Avista).
The proposed settlement wil be filed with FERC in the coming weeks, and the Company does not foresee
any reason for the proposed settlement to be rejected or modified.
XII.
Schedule 155 / Amortization Rate Change
As shown in the table above, the proposed change in the amortization rates are an increase of
approximately 4.7 cents per thermo This increase is a result of the large one-year refund amortization rate
from the 2010 PGA being replaced by a smaller one-year amortization rate. The larger refud balance
from the prior PGA was almost totally amortized in the current PGA year resulting in a reduction in the
refund amortization rate in this PGA. This reduction, coupled with current refund balances of $1.6
milion, results in an increase of approximately 4.7 cents per therm in Schedule 155.
XIII.
The average residential or small commercial customer using 62 therms per month wil see an increase of
$0.99 per month, or approximately 1.63%. The present bil for 62 therms is $60.76 while the proposed bil
is $61.75.
XIV.
Exhibit "e" 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 1,2011.
Applicant requests that, if appropriate, the Commission adopt the procedures prescribed by Rule 201-210,
Modified Procedure. Applicant stands ready for immediate consideration on its Application.
XVI.
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, 2011.
Dated at Spokane, Washington, this 12th day of August 2011.
A VISTA UTILITllS
BY~ ~~i.
Kelly O. Norwood
Vice President, State and Federal Regulation
STATE OF WASHINGTON )
) ss.County of Spokane )
Patrck Ehrbar, being first duly sworn, on oath deposes and says: that he is the Manager of
Rates and Tariffs for A vista Utilties; that he has read the above and foregoing Application, knows
the contents thereof, and believes the same to be tre.
Q~QQ
Patrck D. Ehrbar
Manager, Rates & Tarffs
SUBSCRIED and sworn to before me this iih day of August 2011.
C(~PU~~
State of Washington, residing in
Spokane.
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201 J AUG 'SA U 9fHi : 28
A VISTA UTILITIES
Case No. A VU-G-II-04
EXHIBIT "A"
Proposed Tariff Sheets
August 15, 2011
I.P.U.C. NO.27
Sixteenth Revision Sheet 150
Replacing
Fifteenth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilties
150
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 53.481 ø per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
42.305Ø per thermo
(c) The rate for transportation under Schedule 146 is to be decreased by
O.OOOø per thermo
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 CommoditySchedules 101 11.176Ø 42.305Ø
Schedules 111 and 112 11.176Ø 42.305ØSchedules 131 and 132 .000ø 42.305Ø
The above amounts include a gross revenue factor.
Total
53.481Ø
53.481Ø
42.305Ø
Demand Commodity TotalSchedules 101 11.135Ø 42.148Ø 53.283ØSchedules 111 and 112 11.135Ø 42.148Ø 53.283ØSchedules 131 and 132 .OOOØ 42.148Ø 42.148Ø
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 wil 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.
Issued August 12, 2011 Effective October 1 , 2011
Issued by Avista UtilitiesBy ~ -; :,~orwOOd - VicePresident, State & Federal Regulation
I.P.U.C. NO.2?
Sixteenth Revision Sheet 150
Replacing
Fifteenth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilties
150
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 53.481é per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
42.305é per thermo
(c) The rate for transportation under Schedule 146 is to be decreased by
O.OOOø per thermo
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 CommoditySchedules 101 11.176é 42.305é
Schedules 111 and 112 11.176é 42.305éSchedules 131 and 132 .000é 42.305é
The above amounts include a gross revenue factor.
Total
53.481é
53.481é
42.305é
Demand Commodity TotalSchedules 101 11.135é 42.148é 53.283éSchedules 111 and 112 11.135é 42.148é 53.283éSchedules 131 and 132 .000é 42.148é 42.148é
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company wil 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.
Issued August 12,2011 Effective October 1, 2011
Issued by Avista Utiities
By Kelly O. Norwood - Vice-President, State & Federal Regulation
I.P.U.C. NO.2?
Fifteenth Revision Sheet 150
Replacing
Fourteenth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilties
150
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 56.587Ø per therm in all blocks of these rate schedules.
(b) The rates of interruptible Schedules 131 and 132 are to be increased by
46.101Ø pertherm.
(c) The rate for transportation under Schedule 146 is to be decreased by
O.OOOø per thermo
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 CommoditySchedules 101 10,486Ø 46.101Ø
Schedules 111 and 112 10,486Ø 46.101ØSchedules 131 and 132 .000ø 46.101Ø
The above amounts include a gross revenue factor.
Total
56.587Ø
56.587Ø
46.101Ø
Demand Commodity TotalSchedules 101 10,421Ø 45.817Ø 56.238ØSchedules 111 and 112 10,421Ø 45.817Ø 56.238ØSchedules 131 and 132 .000ø 45.817Ø 45.817Ø
The above amounts do not include a gross revenue factor.
BALANCING ACCOUNT:
The Company wil maintain a Purchase Gas Adjustment (PGA) Balancing
Account whereby monthly entries into this Balancing Account wil 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.
Issued November 5, 2010 Effective January 1, 2011
Issued by Avista Utilities
By Kelly O. Norwood - Vice-President, State & Federal Regulation
I.P.U.C. NO.27
Thirteenth Revision Sheet 155
Canceling
Twelfth Revision Sheet 155
AVISTA CORPORATION
d/b/a Avista Utilities
155
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 2.885Ø per therm in all blocks of these rate schedules.
(b) The rate of interruptible gas Schedule 131 is to be decreased by
3.314Ø per thermo
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 August 12, 2011 Effective October 1, 2011
Issued by Avista Utilities
By Kelly Norwood, Vice President, State & Federal Regulation
?a ~~i.
I.P.U.C. NO.2?
Thirteenth Revision Sheet 155
Canceling
Twelfth Revision Sheet 155
AVISTA CORPORATION
d/b/a Avista Utilities
155
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 2.885t per therm in all blocks of these rate schedules.
(b) The rate of interruptible gas Schedule 131 is to be decreased by
3.314t per thermo
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 August 12, 2011 Effective October 1, 2011
Issued by Avista Utilities
By Kelly Norwood, Vice President, State & Federal Regulation
I.P.U.C. NO.2?
Twelfth Revision Sheet 155
Canceling
Eleventh Revision Sheet 155
AVISTA CORPORATION
d/b/a Avista Utilities
155
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 7.582~ per therm in all blocks of these rate schedules.
(b) The rate of interruptible gas Schedule 131 is to be decreased by
8.091 ~ per thermo
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 September 14, 2010 Effective November 1. 2010
Issued by Avista UtilitiesBy Kelly Norwood, Vice President, State & Federal Regulation
2011 AUG /5
A VISTA UTILITIES 11!', 9: 28
Case No. A VU-G-II-04
EXHIBIT "B"
Notice of Public Applicant's Proposed Tariffs
August 15, 2011
A VISTA UTILITES
NOTICE OF IDAHO TARIF CHANGE
(Natual Gas Service Only)
Notice is hereby given that the "Sheets" listed below ofTariffIPUC No. 27, covering natual gas
service applicable to Idaho customers of A vista Utilties have been filed with the Idaho Public
Utilties Commission (IPUC) in Boise, Idaho.
Sixteenth Revision Sheet 150
Thirteenth Revision Sheet 155
canceling
canceling
Fifteenth Revision Sheet 150
Twelfth Revision Sheet 155
Thirteenth Revision Sheet 155 updates the amortzation rate used to refud or recover previous
gas cost differences and Sixteenth Revision Sheet 150 updates the forward-looking cost of
natual gas purchased for customer usage.
These tariffs request an anual revenue increase of approximately $1.1 milion, or about 1.53%.
This request is a Purchased Gas Cost Adjustment (PGA) that is filed anually 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; A vista makes no
additional profits from these rate changes.
If approved as filed a residential or small business customer served under Schedule 101 using an
average of 62 therms per month can expect to see an average increase of approximately $0.99
per month, or about 1.63%. Larger commercial customers served under Schedules 111 can
expect to see an average increase of about 2.05%, with the higher percentages due to lower base
rates. However, actual customer increases wil vary based on therms consumed.
This filing requests an effective date of October 1, 2011.
Copies of the proposed tariff changes are available for inspection in the Company's offces or can
be obtained by callng [phone] or wrting:
A vista Utilties
Attention: Manager, Rates & Tariffs
P.O. Box 3727
Spokane, WA. 99220-3727
August 15,2011
A VISTA UTILITIES
Case No. AVU-G-11-04
EXHIBIT "C"
Workpapers
August 15, 2011
eEl D
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1
Avista Utilties
State of Idaho
Average Increase Per Customer (From Last GRC)
Sch Average Present Total Proposed Total Estimated Estimated
Mo. Usage Rate Present Rate Proposed Monthly Increase
Per Cust.Cost Cost Increase Percentage
101 62 $0.91553 $56.76 $0.93144 $57.75
Basic Charge $4.00 $4.00 $4.00
$60.76 $61.75 $0.99 1.63%
111 2,023
First 200 $0.93198 $186.40 $0.94789 $189.58
Next 800 $0.79960 $639.68 $0.81551 $652.41
1,0001 - 10,000 $0.72499 $741.66 $0.74090 $757.94
Over 10,000 $0.67583 $0.69174
$1,567.74 $1,599.93 $32.19 2.05%
131 $0.58391 $0.59372 1.68%
132 36,469 $0.66482 $24,245.32 $0.62686 $22,860.96 ($1,384.36)-5.71%
Page 2
Avista Utilties
Calculation of Idaho Proposed Rates
Sch Description Proposed Proposed Proposed Present Present Total
No.Present Schedule Schedule Schedule Schedule Schedule Proposed
Rate 150 155 156 191 (DSM)199 (DSIT)Rate
101 General $0.37515 $0.53481 ($0.02885)$0.05762 ($0.00729)$0.93144
111 Large General
First 200 $0.39516 $0.53481 ($0.02885)$0.05038 ($0.00361)$0.94789
Next 800 $0.26278 $0.53481 ($0.02885)$0.05038 ($0.00361)$0.81551
Next 9,000 $0.18817 $0.53481 ($0.02885)$0.05038 ($0.00361)$0.74090
Over 10,000 $0.13901 $0.53481 ($0.02885)$0.05038 ($0.00361)$0.69174
112 Large General
First 200 $0.39516 $0.53481 $0.05038 ($0.00361)$0.97674
Next 800 $0.26278 $0.53481 $0.05038 ($0.00361)$0.84436
Next 9,000 $0.18817 $0.53481 $0.05038 ($0.00361)$0.76975
Over 10,000 $0.13901 $0.53481 $0.05038 ($0.00361)$0.72059
131 Interruptible $0.16647 $0.42305 ($0.03314)$0.04020 ($0.00286)$0.59372
132 Interruptible $0.16647 $0.42305 $0.04020 ($0.00286)$0.62686
146 Transportation $0.10559 ($0.00159)$0.10400
Page 3
Avista Utilties
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 $0.37515 $0.56587 ($0.07582)$0.05762 ($0.00729)$0.91553
111 Large General
First 200 $0.39516 $0.56587 ($0.07582)$0.05038 ($0.00361)$0.93198
Next 800 $0.26278 $0.56587 ($0.07582)$0.05038 ($0.00361)$0.79960
1,0001 - 10,000 $0.18817 $0.56587 ($0.07582)$0.05038 ($0.00361)$0.72499
Over 10,000 $0.13901 $0.56587 ($0.07582)$0.05038 ($0.00361)$0.67583
112 Large General
First 200 $0.39516 $0.56587 $0.05038 ($0.00361)$1.00780
Next 800 $0.26278 $0.56587 $0.05038 ($0.00361)$0.87542
1,0001 - 10,000 $0.18817 $0.56587 $0.05038 ($0.00361)$0.80081
Over 10,000 $0.13901 $0.56587 $0.05038 ($0.00361)$0.75165
131 Interruptible $0.16647 $0.46101 ($0.08091)$0.04020 ($0.00286)$0.58391
132 Interruptible $0.16647 $0.46101 $0.04020 ($0.00286)$0.66482
146 Transportation $0.10559 ($0.00159)$0.10400
Page 4
Avista Utilties
State of Idaho
Recap of Rate Changes Including GRF
Previous Proposed Increase
Rate Rate -:Decrease~
Schedule 150 (Gas Costs)
Schedule 101 $0.56587 $0.53481 ($0.03106)
Schedule 111 $0.56587 $0.53481 ($0.03106)
Schedule 112 $0.56587 $0.53481 ($0.03106)
Schedule 131 $0.46101 $0.42305 ($0.03796)
Schedule 132 $0.46101 $0.42305 ($0.03796)
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 $0.00000
Schedule 146 $0.00000 $0.00000 $0.00000
Schedule 155 (Gas Cost Amortization)
Schedule 101 ($0.07582)($0.02885)$0.04697
Schedule 111 ($0.07582)($0.02885)$0.04697
Schedule 112 $0.00000 $0.00000 $0.00000
Schedule 131 ($0.08091)($0.03314)$0.04777
Schedule 132 $0.00000 $0.00000 $0.00000
Schedule 146 $0.00000 $0.00000 $0.00000
Combined Schedule 150,155 & 156
Schedule 101 $0.49005 $0.50596 $0.01591
Schedule 111 $0.49005 $0.50596 $0.01591
Schedule 112 $0.56587 $0.53481 ($0.03106)
Schedule 131 $0.38010 $0.38991 $0.00981
Schedule 132 $0.46101 $0.42305 ($0.03796)
Schedule 146 $0.00000 $0.00000 $0.00000
Page 5
Avista Utilties
State of Idaho. Weighted Average Cost of Gas
For 10/1111 .10/31112 (13 Months)
NORTHWEST PIPELINE
TF.2 Demand Charge
TF-2 Variable Transportation Charge
SGS.1 Commodity Washington
Idaho
TF-1 Demand Charge
End User Capacity Releases
Variable Transportation Charge
CANADIAN PIPELINES
TCPL Alberta (NOVA) Demand
TCPL. BC (ANG . FOOTHILLS)
GTN Demand
GTN Variable Transportation Charge
Spectra Energy. Westcoast Energy
OTHER
Gas Purchases
Capacity Releases
Terasen Reservation Credit
GRI Funding
Total
Note 1 . Based on 5 day peak study
Note 2 . Annual Commodity Percentage
Annual System 13 Mos System Idaho Idaho
Biling Billng Rate System Demand Commodity
Determinants Determinants Per Therm Total Cost Costs (1)Costs (2)
(Therms)(Therms)30.420%30.358%
29,140,920 31,569,330 $0.037984 $1,199,129 $364,775
54,337,250 $0.003000 $163,012 $49,487
38,336,470 $0.390500 $14,970,392
16,000,780 $0.390500 $6,248,305 $6,248,305
559,621,000 606,256,083 $0.037984 $23,028,031 $7,005,127
2,555,000 2,767,917 $0.037984 $105,136
85,582,220 $0.003190 $273,007 $82,879
345,375,290 378,263,670 $0.01978 $7,483,132 $2,276,369
52,564,015 57,028,356 $0.06259 $3,569,676 $1,085,895
363,275,760 $0.00908 $3,298,474 $1,003,396
125,000,000 $0.00058 $72,500 $22,010
29,234,170 31,670,351 $0.04456 $1,411,199 $429,287
64,215,210 $0.45703 $29,348,277 $29,348,277
($10,800,000)($3,285,360)
($6,500,000)($1,973,270)
$32,000
118,552,460 $73,870,270 $8,879,489 $33,809,688
Estimated Therms 79,746,077 80,216,022
Proposed WACOG $0.53283 $0.11135 $0.42148
Gross Revenue Factor (GRF)100.3718%100.3718%100.3718%
Proposed WACOG Including GRF $0.53481 $0.11176 $0.42305
Present Gas Costs Including GRF $0.56587 $0.10486 $0.46101
Rate Change Including GRF ($0.03106)$0.00690 ($0.03796)
Sch 101 Sch 101
Sch 111 Sch 111
Sch 112 Sch 112
Sch 131
Sch 132
Page 6
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Avista Utilties
State of Idaho
Total Gas Costs Without GRF
For 1011/11 -10/31/12 (13 Months)
Demand Commodity Total
Proposed Gas Costs Before GRF
Schedules 101 - 112 $0.11135 $0.42148 $0.53283
Schedules 131 - 132 $0.42148 $0.42148
Present Gas Costs Before GRF
Schedules 101 - 112 $0.10421 $0.45817 $0.56238
Schedules 131 - 132 $0.45817 $0.45817
Increase oeDecrease~ Before GRF
Schedules 101 - 112 $0.00714 ($0.03669)($0.02955)
Schedules 131 - 132 ($0.03669)($0.03669)
Proposed Gas Costs Including GRF
Schedules 101 . 112 $0.11176 $0.42305 $0.53481
Schedules 131 - 132 $0.42305 $0.42305
Present Gas Costs Including GRF
Schedules 101 - 112 $0.10486 $0.46101 $0.56587
Schedules 131 - 132 $0.46101 $0.46101
Increase oeDecrease~ Including GRF
Schedules 101 - 112 $0.00690 ($0.03796)($0.03106)
Schedules 131 - 132 ($0.03796)($0.03796)
Page 8
Avista Utilties
State of Idaho
Northwest Pipeline
Rate Contract Number Annual Daily Annual 13 Month
Contract Effective Demand of Contract Rate System System
Number Rate Schedule Date (Dth's)Days Demand (Note 1)Costs Costs
(Dth's)
100010 TF-1 Firm Transportation 8/1/10 133,270 366 48,776,820 $0.37984 $18,527,387 $20,071,336
100164 TF-1 Firm Transportation 8/1/10 10,000 366 3,660,000 $0.37984 $1,390,214 $1,506,065
100314 TF-2 Jackson Prairie 8/1/10 7,962 366 2,914,092 $0.37984 $1,106,889 $1,199,130
136948 TF-1 Firm Transportation 8/1/10 5,000 366 1,830,000 $0.37984 $695,107 $753,033
136950 TF-1 Firm Transportation 8/1/10 5,330 366 1,950,780 $0.37984 $740,984 $802,733
Total Firm Transportation 59,131,692 $ 22,460,581 $ 24,332,297
Less: TF-2 Jackson Prairie (2,914,092)(1,106,889)($1,199,130)
Less: End User Capacity Releases (255,500)(97,049)($105,136)
Net TF-1 Firm Transportation 55,962,100 $ 21,256,643 $ 23,028,031
Note 1 -From NWP First Revised Sheet No.5, Fifth Revised Volume No. 1
TF-1, Large Customer, System-Wide (MMBTu) effective 7/21/11
Page 9
A vista Utilties
State of Idaho
Gas Transmission NW Corporation
FTS.1 FTS-1 FTS-1 FTS-1 System
F-00177 F.00177 F-00178 F-002591 Total
(Oct - Mar)(Apr - Sept)
MMBTu's 54,823 30,000 20,782 25,000
Number of Effective Days (13 Mo~214 214 397 397
13 Months MMBTu's 11,732,122 6,420,000 8,250,454 9,925,000 36,327,576
10/1/11 - 12/31/11 Volumes 5,043,716 2,760,000 1,911,944 2,300,000 12,015,660
1/1/12 - 10/31/12 Volumes 6,688,406 3,660,000 6,338,510 7,625,000 24,311,916
11,732,122 6,420,000 8,250,454 9,925,000 36,327,576
Daily Non-Mileage Rate (Note 1)$0.036632 $0.036632 $0.036632 $0.036632
Daily Non-Mileage Rate (Note 2)$0.039196 $0.039196 $0.039196 $0.039196
Mileage Rate (Note 1)$0.000463 $0.000463 $0.000463 $0.000463
Mileage 103.39 102.96 117.22 108.29
Total Mileage Rate $0.047870 $0.047670 $0.054270 $0.050140
Mileage Rate (Note 2)$0.000498 $0.000498 $0.000498 $0.000498
Mileage 103.39 102.96 117.22 108.29
Total Mileage Rate $0.051490 $0.051270 $0.058380 $0.053930
Fixed 13 Month Amount $446,920 $244,561 $318,482 $383,124 1,393,087
13 Month Mileage Based Amount $585,829 $319,217 $473,803 $526,538 1,905,387
Total 13 Month Amount $1,032,749 $563,778 $792,285 $909,662 $3,298,474
Note 1 . Gas Transmission NW, Fourth Revised Volume No.1-A, Part 4.1
Effective 5/04/11
Note 2 - Gas Transmission NW, Fourth Revised Volume No.1-A, Part 4.1
Proposed to be effective 1/1/12
Page 10
Avista Utilties
State of Idaho
TransCanada Pipeline - Foothils (ANG)
Daily Annual 13 Months
Daily Annual Mileage Mileage Mileage
Contract No. of Contract Rate Miles Costs Costs
Demand (Gj)Mos Demand (Gj)(Note 1)
AVA - F3 (Firm)31,100 12 373,200 $0.01585217 170.7 $1,009,866 $1,094,022
WWP - FI (Firm)58,284 6 349,704 $0.01585217 170.7 $946,287 $1,104,002
WWP - FI (Firm)31,892 6 191,352 $0.01585217 170.7 $517,792 $604,091
AVA-F2 7,159 6 42,954 $0.01585217 170.7 $116,232 $135,604
AVA-F2 22,508 12 270,096 $0.01585217 170.7 $730,871 $791,777
WWP - F3 (Firm)16,441 12 197,292 $0.01585217 170.7 $533,865 $578,354
WWP - F3 (Firm)16,817 12 201,804 $0.01585217 170.7 $546,075 $591,581
184,201 1,626,402 $4,400,988 $4,899,431
Canadian Exchange Rate 100%100%
$4,400,988 $4,899,431
Less: Oregon Portion 47,705 $1,139,790 $1,329,755
Total 136,496 $3,261,198 $3,569,676
Annualized Therms
GJ to Dth Conversion Factor 1.055056
Dth Per Day 144,011
Days 365
WAID Annualized Therms 52,564,015
Note 1 - FT Firm Service Rate, effective January 1, 2011 (Canadian cents/Gj/KmlMonth)
Page 11
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Avista Utilities
State of Idaho
Westcoast Energy - Demand Calculation
Rate Schedule FT-D, Appendix A, Effective 4/1/11
Demand Rate per month (C$)
(10 cubedlm cubed)
Daily Demand (*12 mos/366 days)
Convert to GJ (/38.25)
Convert to MMBtu's (*1.055056)
Convert to U.S. Dollars
Billng Determinants
Contract Demand E3M3
Number of Days
Annual Contract Demand E3M3
Conversion Factor
GJ
Conversion Factor
Dth
Total Annual Costs
Total 13 Months Costs (Annual Costs i 12Mos * 13Mos)
Page 13
$492.71
$16.1544
$0.422338
$0.445590
100%
220.32
366
80,637.1
38.25
3,084,369
1.055056
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2,923,417
$1,302,645
$1,411,199
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Avista Utilities
State of Idaho
Recap of Changes To Schedule 150/156
Anticipated Effect Date 10/1/11
CENTS PER THERM Commodity TotalDemand Charge
Schedule 101
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.46101
(0.03796)
0.42305
Schedule 111
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.46101
(0.03796)
0.42305
Schedule 112
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.46101
(0.03796)
0.42305
Schedule 131
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.46101
(0.03796)
0.42305
Schedule 132
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.46101
(0.03796)
0.42305
Schedule 146
Current Rate
Proposed Incr-eDecr::
Proposed Rate
0.10486
0.00690
0.11176
0.10486
0.00690
0.11176
0.10486
0.00690
0.11176
0.56587
(0.03106)
0.53481
0.56587
(0.03106)
0.53481
0.56587
(0.03106)
0.53481
0.46101
(0.03796)
0.42305
0.46101
(0.03796)
0.42305
Page 15
Avista Utilties
State of Idaho
Calculation of Changes to Schedule 155
Firm Customers, Schs 101 & 111
Firm Customers, Schedules 112
Interruptible Customers, Schedules 131
Interruptible Customers, Schedules 132
Transportation Customers, Schedules 146
Current
Rate
Incr c:Decr:
Proposed
Rate
Incr c:Decr:
Total
Proposed
Incr c:Decr:
($0.07582)
($0.08091)
Page 16
($0.02885)
($0.03314)
$0.04697
$0.04777
Avista Utilties
Idaho Gas Tracker
Calculation of New Amortization Rate
Schedule 155
Schedule 111
Amortization Total
All Firm All Sales Rate Revenue Amortization
Customers Customers Before GRF Adjustment Rate
$0.00428 ($0.03302)($0.02874)($0.00011)($0.02885)
$0.00428 ($0.03302)($0.02874)($0.00011)($0.02885)
Schedule 101
Schedule 112
Schedule 131 ($0.03302)($0.03302)($0.00012)($0.03314)
Schedule 132
Page 17
Avista Utilities
Idaho Gas Tracker
Balances at 6/30/11
Unamortized Current
Deferrals Deferrals Total Adjustments Total
At 6/30/11 At 6/30/11
(Acct 191000)(Acct 191010)
All Firm Customers 1,779,700.67 (1,439,952.56)339,748.11 339,748.11
All Sales Customers (2,480,406.48)(141,932.88)(2,622,339.36)(2,622,339.36)
Customer 1 (57,503.42)(1,017.37)(58,520.79)(58,520.79)
Customer 2 (22.44)(78.37)(100.81)(100.81)
Customer 3 (3,437.77)(3,437.77)(3,437.77)
Customer 4 (37,087.85)(1,922.16)(39,010.01 )(39,010.01 )
(798,757.29)(1,584,903.34)(2,383,660.63)(2,383,660.63)
Page 18
Avista Utilties
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 $0.00428 1.00%Amortized
$339,748.11
October 2011 3,577,303 1,810,187 5,387,490 ($23,058.46)$273.52 316,963.17
November 6,796,882 2,691,202 9,488,084 (40,609.00)247.22 276,601.39
December 2012 9,156,578 3,055,566 12,212,144 (52,267.98)208.72 224,542.13
January 8,778,247 2,784,979 11,563,226 (49,490.61 )166.50 175,218.02
February 7,078,475 2,338,155 9,416,630 (40,303.18)129.22 135,044.06
March 6,073,804 1,988,678 8,062,482 (34,507.42)98.16 100,634.80
April 4,385,877 1,372,997 5,758,874 (24,647.98)73.59 76,060.41
May 2,357,918 1,086,384 3,444,302 (14,741.61)57.24 61,376.04
June 1,508,835 792,190 2,301,025 (9,848.39)47.04 51,574.69
July 1,254,356 808,245 2,062,601 (8,827.93)39.30 42,786.06
August 1,418,985 651,268 2,070,253 (8,860.68)31.96 33,957.34
September 1,570,635 977,272 2,547,907 (10,905.04)23.75 23,076.05
October 2012 3,576,263 1,854,796 5,431,059 (23,244.93)9.54 (159.34)
57,534,158 22,211,919 79,746,077 ~$341,313.21)$1,405.76
Page 19
Avista Utilties
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 ($0.03302)1.00%Amortized
($2,622,339.36)
October 2011 3,577,303 1,810,187 5,387,490 $177,894.92 ($2,111.16)(2,446,555.60)
November 6,796,882 2,691,202 9,488,084 313,296.53 (1,908.26)(2,135,167.33)
December 9,156,578 3,055,566 12,212,144 403,244.99 (1,611.29)(1,733,533.63)
January 2012 8,778,247 2,784,979 11,563,226 381,817.72 (1,285.52)(1,353,001.43)
February 7,078,475 2,338,155 9,416,630 310,937.12 (997.94)(1,043,062.25)
March 6,073,804 1,988,678 8,062,482 266,223.16 (758.29)(777,597.38)
April 4,385,877 1,372,997 5,758,874 190,158.02 (568.77)(588,008.13)
May 2,357,918 1,086,384 3,444,302 113,730.85 (442.62)(474,719.90)
June 1,508,835 792,190 2,301,025 75,979.85 (363.94)(399,103.99)
July 1,254,356 808,245 2,062,601 68,107.09 (304.21)(331,301.11 )
August 1,418,985 651,268 2,070,253 68,359.75 (247.60)(263,188.96)
September 1,570,635 977,272 2,547,907 84,131.89 (184.27)(179,241.34)
October 2012 3,576,263 1,854,796 5,431,059 179,333.57 (74.65)17.58
57,534,158 22,211,919 79,746,077 $2,633,215.46 ($10,858.52)
Page 20
Avista Utilties
Idaho Gas Tracker
Revenue Adjustment Factor
From General Rate Case AVU-G-11-01, Filed 7/05/11
Commission Fees
Uncollectibles
Calculation of Revenue Adjustment Factor
1 1(1 - 0 ) =
$0.002039
$0.001665
Page 21
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1.003718
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r
r
a
l
s
De
f
e
r
r
a
l
i
._
-
-
~
~
_.
_
-
-
-
-
-
-
~
Cu
s
t
o
m
e
r

1
(1
4
.
5
9
)
(3
3
,
3
9
6
.
9
4
)
(1
3
,
7
5
6
.
2
0
)
1
75
0
.
2
3
(3
3
.
2
5
)
(4
6
,
4
3
6
.
1
6
)
(1
2
,
8
5
9
.
5
8
)
--
-
i
Cu
s
t
o
m
e
r

2
0.
0
5
61
.
1
5
I
0.
0
5
61
.
2
0
Cu
s
t
o
m
e
r

3
!
Cu
s
t
o
m
e
r

4
(1
7
.
8
2
)
(2
6
,
4
5
2
.
7
9
)
+-
(2
6
.
2
5
)
(1
0
,
1
Q
2
.
0
~
1
J
t
~
_
_
_
(3
6
,
5
8
1
.
0
5
)
(6
,
7
7
1
.
4
2
)
J
--
-
~
-
-
~
-
-
-
~
-
_
.
i
._
-
_
,
_
~
-
-
"
-
'
-
-
-
-
'
-
-~
-
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-
+
Fi
r
m

C
u
s
t
o
m
e
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s
22
0
.
2
1
47
6
,
9
0
7
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2
8
l=
1
5
.
9
6
55
8
.
9
2
86
5
,
0
8
2
.
1
6
Sa
l
e
s

C
u
s
t
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s
(1
,
7
6
5
.
0
1

)
(2
,
4
8
9
,
1
2
0
.
0
4
)
(8
6
1
,
3
.
?
~
.
!
Ù
)

_
_
(2
,
4
3
3
.
1
7
)
(3
,
3
5
2
,
9
2
7
.
0
2
)
(6
5
8
,
1
8
1
.
5
7
)
-_
.
_
~
-
-
-
~
-
-
-
-
-
-
-
-
i
._
_
.
.
.
-
-
-
,
-
-
-
-
-
_
.
.
,
-
-
_
.
.
.
(1
,
5
7
7
.
1
6
)
(2
,
0
7
2
,
0
0
1
.
3
4
)
(8
8
5
,
2
3
2
.
0
2
)
38
8
,
3
6
6
.
1
9
(1
,
9
3
3
.
7
0
)
(2
,
5
7
0
,
8
0
0
.
8
7
)
(6
7
7
,
8
1
2
.
5
7
)
OK
OK
Pa
g
e

2
9
Av
i
s
t
a

U
t
i
l
t
i
e
s
St
a
t
e

o
f

I
d
a
h
o
Re
c
a
p

o
f

A
c
c
t

1
9
1
0
1
0
~-
-
--
-
-
~
-
-
-
~
-
~
-
-
-
--
De
m
a
n
d

&
in
t
e
r
e
~
i
Ba
l
a
n
c
e
1
PG
A
,
11
/
3
0
/
1
0
De
m
a
n
d

&

i

I
n
t
e
r
e
s
t
~-
-
-
-
-
i
Ca
p
a
c
i
t
y

R
e
I
.

I
-_
.
_
-
Ca
p
a
c
i
t
y

R
e
I
.
10
/
3
1
/
1
0
Tr
a
n
s
f
e
r
Co
m
m
o
d
i
t
y
~-
-
De
f
e
r
r
a
l
s

!
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
--
-
~
~
-
-
Î-
~
-
-
~
iL_
~
_
_
_
--
-
-
-
-
-
-
-
-
-
-
-
--
-
-
-
-
-
-
-
-
~
-
-
Cu
s
t
o
m
e
r

1
57
5
.
0
8
(4
3
.
8
2
)
(5
8
,
7
6
4
.
4
8
)
58
,
7
6
4
.
4
8
3,
1
0
3
.
4
0
(1
,
3
0
1
.
5
0
)
0.
7
5
--
-
~
-
Cu
s
t
o
m
e
r

2
0.
0
5
61
.
2
5
(6
1
.
2
5
)
9.
9
8
(3
8
.
0
3
)
(0
.
0
1

)
-
--
-
Cu
s
t
o
m
e
r

3
--
-
-
-
-
-
-
Cu
s
t
o
m
e
r

4
(3
3
.
3
1

)
(4
3
,
3
8
5
.
7
8
)
43
,
3
8
5
.
7
8
2,
1
4
1
.
6
9
_
j

0
.
8
9
r=
~
~
-
_
=
_
=
=
~
-
-
-
(3
7
6
,
4
6
9
.
9
7
r
0
5
6
.
8
6
)
Fi
r
m

C
u
s
t
o
m
e
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s
21
3
,
9
2
9
.
8
6
81
0
.
0
5

i

1
,
0
7
9
,
8
2
2
.
0
7
(1
,
0
7
9
,
8
2
2
.
0
7
)
--
-
-
-
-
-
-
-
-
-
-
-
-
-
Sa
l
e
s

C
u
s
t
o
m
e
r
s
i
(
3
,
0
6
8
.
3
5
)
1

(
4
,
0
1
4
,
1
7
6
.
9
4
)
4,
0
1
4
,
1
7
6
.
9
4
32
0
,
5
0
5
.
3
3
13
3
.
5
4
r-
-
-
-
-
-
-

-
--
-
-
-
-
-
-
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21
4
,
5
0
4
.
9
4
(2
,
3
3
5
.
3
8
)
(3
,
0
3
6
,
4
4
3
.
8
8
)
3,
0
3
6
,
4
4
3
.
8
8
32
5
,
7
6
0
.
4
0
(3
7
7
,
8
0
9
.
5
0
)
(2
1
.
6
9
)
OK
Pa
g
e

3
0
Av
i
s
t
a

U
t
i
l
t
i
e
s
St
a
t
e

o
f

I
d
a
h
o
Re
c
a
p

o
f

A
c
c
t

1
9
1
0
1
0
ii
Ba
l
a
n
c
e
12
/
3
1
/
1
0
De
m
a
n
d

&
In
t
e
r
e
s
t
Ba
l
a
n
c
e
1/
3
1
/
1
1
De
m
à
n
d

&
In
t
e
r
e
s
t
!I
--
-
~
--
-
11
/
3
0
/
1
0

C
o
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
12
/
3
1
/
1
0
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
=t

D
e
f
e
r
r
a
l
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
De
f
e
r
r
a
l
s
--
Cu
s
t
o
m
e
r

1
--
~
~
-
~
+
-
-
-

-
(0
.
2
1
)
(1
,
8
5
7
.
7
3
)
(5
4
.
5
6
)
~
1
,
8
0
2
.
6
5

~
0.
7
3
(0
.
0
5
)
Cu
s
t
o
m
e
r

2
;
(
2
8
.
0
6
)
,
(5
.
6
7
)
(5
3
.
1
6
)
(0
.
0
5
)
(8
6
.
9
4
)
43
.
3
4
(4
7
.
3
2
)
(0
.
0
7
)
Cu
s
t
o
m
e
r

3
Cu
s
t
o
m
e
r

4
¡
2
,
1
4
2
.
5
8
1

(
1
7
9
.
4
7
)
1.
7
1
-
+
_
_
_
_
_
_
_
1
,
9
6
4
.
8
2

i
85
2
.
3
8
1.
9
9
TI
7
6
,
6
2
6
.
8
3
)

I
i_
Fi
r
m

C
u
s
t
o
m
e
r
s
(5
4
5
,
8
5
8
.
8
2
)
(5
4
1
.
3
0
)
1
(9
2
3
,
0
2
6
.
9
5
)
(5
3
1
,
0
0
6
.
1
8
)
(9
9
0
.
4
4
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
__
!
_
_

3
2
0
,
6
3
8
.
8
7
(4
6
,
2
4
3
.
7
5
)
24
7
.
9
3
27
4
,
6
4
3
.
0
5
!

2
2
4
,
8
7
5
.
3
0
32
2
.
5
7
--
-
-
_
.
.
_
-
-
--
-
(5
2
,
0
7
0
.
7
9
)
(4
6
,
4
2
9
.
1
0
)
(5
4
7
,
7
6
9
.
7
1

)
(2
9
0
.
9
8
)
(6
4
6
,
5
6
0
.
5
8
)
22
5
,
7
7
1
.
0
2
(5
3
1
,
0
5
3
.
5
0
)
(6
6
6
.
0
0
\
OK
OK
Pa
g
e

3
1
Av
i
s
t
a

U
t
i
l
i
t
i
e
s
St
a
t
e

o
f

I
d
a
h
o
Re
c
a
p

o
f

A
c
c
t

1
9
1
0
1
0
..
j
Ba
l
a
n
c
e
2/
2
8
/
1
1
De
m
a
n
d

&

i

I
n
t
e
r
e
s
t
Ba
l
a
n
c
e
3/
3
1
/
1
1
De
m
a
n
d

&
1/
3
1
/
1
1
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y
_
R
e
I
.
2/
2
8
/
1
1
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
.
.
.
De
f
e
r
r
a
l
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
De
f
e
r
r
a
l
s
.-
--
-
-
-
._
-
-
-
-
-
Cu
s
t
o
m
e
r

1
(5
4
.
6
1

)
(0
.
0
5
)
(5
4
.
6
6
)
Cu
s
t
o
m
e
r

2
(9
0
.
9
9
)
12
.
7
2
(3
e
:
9
2
)
(0
.
0
9
)
(1
1
7
.
2
8
)
61
.
0
1
(1
6
.
4
8
)
Cu
s
t
o
m
e
r

3
.
Cu
s
t
o
m
e
r

4
2,
8
1
9
.
1
9
30
2
.
3
4
2.
4
8
3,
1
2
4
.
0
1
1,
1
7
9
.
0
9
~-_
.
_
.
_
-
-
-
-

,
.

.
.

_
.
.
.
_
_
.
.
_
-
"
'
-
-
-
-
-
-
-
-
~
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e-
.
_
-
-
i
-
.
._
.
.
--
-
~
.
~
.
_
.

.
.
.
.
.
.
_
-
-
-
Fi
r
m

C
u
s
t
o
m
e
r
s
(1
,
4
5
5
,
0
2
3
.
5
7
)
(3
9
9
,
1
9
9
.
4
5
)
(1
,
3
7
8
.
8
5
)
(1
,
8
5
5
,
6
0
1
.
8
7
)
(1
5
3
,
8
7
2
.
2
0
)
--
-
~
.
-
-
-
-
-
~
Sa
l
e
s

C
u
s
t
o
m
e
r
s
49
9
,
8
4
0
.
9
2
80
,
8
8
6
.
5
6
45
0
.
2
4
58
1
,
1
7
7
.
7
2
30
0
,
9
6
3
.
8
6
..
--
(9
5
2
,
5
0
9
.
0
6
)
81
,
2
0
1
.
6
2
(3
9
9
,
2
3
8
.
3
7
)
(9
2
6
.
2
7
)
(1
,
2
7
1
,
4
7
2
.
0
8
)
30
2
,
2
0
3
.
9
6
(1
5
3
,
8
8
8
.
6
8
)
..

.

.
.
.
.
.
_
-
-
-
-
_
.
_
_
.
_
-
-
-
_
.
_
-
-
-
_
.
_
-
-
-
-
-
-
-
-
_
.
_
-
-
OK
...
...

.
.
.
.
..
.
.
O
K
Pa
g
e

3
2
Av
i
s
t
a

U
t
i
l
i
t
i
e
s
St
a
t
e

o
f

I
d
a
h
o
Re
c
a
p

o
f

A
c
c
t

1
9
1
0
1
0
I
.
De
m
a
n
d
In
t
e
r
e
s
t
Ba
l
a
n
c
e
4/
3
0
/
1
1
De
m
a
n
d

&
In
t
e
r
e
s
t
Ba
l
a
n
c
e
5/
3
1
/
1
1
--
-
.
.
_
_
.
.-
De
f
e
r
r
a
l
3/
3
1
/
1
1
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
i
'
4/
3
0
/
1
1
Co
m
m
o
d
i
t
y
-_
.
.
_
-
-
-
-
-
-
-
-
-
-
_
.
Co
r
r
e
c
t
i
o
n

I
_.

.
-
De
f
e
r
r
a
l
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
--
-
~
.
_.
_
_
.
_
.
.
_
.
.
.
_
_
.
.
.
.
_
-
_
.
_
.
Cu
s
t
o
m
e
r

1
86
.
0
7
(0
.
0
1

)
31
.
4
0
(8
7
.
3
1

)
(2
7
2
.
0
0
)
(0
.
1
2
)
(3
2
8
.
0
3
)
(9
1
4
.
6
1

)
~_
.
_
_
.
.
_
_
.
_
-
-
-
_
.
.
Cu
s
t
o
m
e
r

2
4.
9
3

1
-
-

(
0
.
0
8
)
(6
7
.
9
0
)
(1
.
4
8
)
(8
.
7
9
)
(0
.
0
6
)
(7
8
.
2
3
)
.
Cu
s
t
o
m
e
r

3
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Washington Water Power Company
State of Idaho
Analysis of Account 191010
Demand &
Total Commodity Cap. Rei'Interest
Acct191010 Deferral Deferral
6/30/10 Ending Balance (1,363,390.57)(955,639.86)(401,973.44)(5,777.27)
7/31/10 Current Deferrals (350,093.13)(809,712.91 )459,619.78
Estimated Interest (1,282.04)(1,282.04)
7/31/10 Ending Balance (1,714,765.74)(1,765,352.77)57,646.34 (7,059.31)
8/31/10 Current Deferrals (355,658.44)(781,134.54)425,476.10
Estimated Interest (1,577.16)(1,577.16)
8/31110 Ending Balance (2,072,001.34)(2,546,487.31 )483,122.44 (8,636.47)
9/30/10 Current Deferrals (496,865.83)(885,232.02)388,366.19
Estimated Interest (1,933.70)(1,933.70)
9/30/10 Ending Balance (2,570,800.87)(3,431,719.33)871,488.63 (10,570.17)
10/31/10 Current Deferrals (463,307.63)(677 ,812.57)214,504.94
Estimated Interest (2,335.38)(2,335.38)
10/31/10 Ending Balance (3,036,443.88)(4,109,531.90)1,085,993.57 (12,905.55)
11/30/10 Current Deferrals (52,049.10)325,760.40 (377,809.50)
PGA Transfer 3,036,443.88 4,109,531.90 (1,085,993.57)12,905.55
Estimated Interest (21.69)(21.69)
11/30/10 Ending Balance (52,070.79)325,760.40 (377,809.50)(21.69)
12/31/10 Current Deferrals (594,198.81 )(46,429.10)(547,769.71 )
Estimated Interest (290.98)(290.98)
12/31/10 Ending Balance (646,560.58)279,331.30 (925,579.21 )(312.67)
1/30/11 Current Deferrals (305,282.48)225,771.02 (531,053.50)
Estimated Interest (666.00)(666.00)
1/30/11 Ending Balance (952,509.06)505,102.32 (1,456,632.71 )(978.67)
3/1/11 Current Deferrals (318,036.75)81,201.62 (399,238.37)
Estimated Interest (926.27)(926.27)
311/11 Ending Balance (1,271,472.08)586,303.94 (1,855,871.08)(1,904.94)
3/31/11 Current Deferrals 148,315.28 302,203.96 (153,888.68)
Demand Def. Corr.51,353.09 51,353.09
Estimated Interest (976.40)(976.40)
3/31/11 Ending Balance (1,072,780.11 )888,507.90 (1,958,406.67)(2,881.34)
Page 35
Washington Water Power Company
State of Idaho
Analysis of Account 191010
Demand &
Total Commodity Cap. Rei'Interest
Acct 191010 Deferral Deferral
4/30/11 Current Deferrals (592,957.11 )(507,267.97)(85,689.14)
Estimated Interest (1,141.03)(1,141.03)
4/30/11 Ending Balance (1,666,878.25)381,239.93 (2,044,095.81 )(4,022.37)
5/31/11 Current Deferrals (13,896.25)(282,542.55)268,646.30
Estimated Interest (1,394.86)(1,394.86)
5/31/11 Ending Balance (1,682,169.36)98,697.38 (1,775,449.51 )(5,417.23)
6/30/11 Current Deferrals 98,626.73 (244,664.23)343,290.96
Estimated Interest (1,360.71)(1,360.71)
6/30/11 Ending Balance (1,584,903.34)(145,966.85)(1,432,158.55)(6,777.94)
Page 36
A VISTA UTILITIES
Case No. A VU-G-11-04
EXHIBIT "D"
Pipeline Tariffs
August 15, 2011
RECEI í'
l311 AUG 15 Arf 9: 28
au T:rion. Noi: LtcPE au TIr
fou ~ Volu No. I-A
PWFmI
11/""1 .
STATE OF EfCT RATE AN CHOE FOR
TRSPO:RTATION OF NATU GA
Ra Sd Fr- i an LFS..1
RSl3VATIONDAYMIB(a)(DMn)
Mg Mi
BASE (~O.OO
",",_"""".,
STP (e) (e) 0.~~00
EXENSION CHG!
MEOR
tiYNQ..MIGB(h) PELY (e)(n) (DMI)
~ Mi.~.~O'-'W~_~::---"
(0.0,3919f ,"0.o0 0.~~16/0.~~16 O.OO5O1,.~."-_._.... .
. (&)0.o00.00016 0.~~16 0.0050 ).~~%
M5 M'~m.
B-1 (f)0.003290 0.o0 0.00'8 0.o0 0.00 0.006
0.o0 0.o0B-2 (1 0.ooi620 0.o0(W
E.2 (h 0.0091 0.o0(D t)
E-2()() 0.001166 0.o0(D2)
COYOT SPRIS
0.0~0 0.o0
0.o0 0.o0
Ft.:d)
(DMIL.))f .....
"
¡
E:3 (i) 0.0014 12 0.o0 0.001420 0.~~00 0.o0 0.o0 ..
OVEtJ CHOB 0)
SUCHQES
ACA(k)
Isve Au 5, 2011i~mmve: .Jan 1, 2012
_w_"~'~"":~'Ä"""""'"""""~~'""..",,,,...,",,,;:,,,,,,,,_, '....,.. _..~" '.~' ,-,"
0.00190 0.00190
-
IX,cke'N..I~:
Gas TranmissionNorthwest LLC
FERC Gas Tariff
Four Revsed Volui:eNo.i-A
PART 4.1
4.1 .. Statement of Rates
FTS-l and LFS- i Rates
v.2.0.0 Superseding V.l.O.O
STATEMENT OF EFFECnVE RATES AN CHAGES FOR
TRASPORTATION OF NATURAL GAS
Rate Schedules FTS- i an LFS-l
RESERVATIONDAIY DAIY
MIEAGE(a) NON-MJEAGE(b) DELIVRY(c)(D-MIE)(D) (D-MILE)
STF (e)0.00000
Ma. Mi Max. Minr""'~" " .",-#,.-~~~,,,.~,,,
p.0%632)._ (Q,lllo/ O.QOlil" /-
(er 0.o0 0.00016 0.~~16
FUEL(d)
(nh-MIE)
Max. Mi
BASE 0.0050% 0.0000%
(e)0.0050% O.OO/e
EXTENSION CHAGES
MEDFORD
E-l (f) 0.003290 0.00000 0.005498 0.~~00 0.000026 0.~~26
E-2 (g)(l) 0.008620 0.00~~Ç')0.0~0 0.o0
E-2 (h)(l) 0.002972 0.0~0
(Diamond 1)
E-2(h)(1) 0.001166 0.o0
(Diamond 2)
O.OO 0.o0
0.0~0 0.00000
COYOTE SPRlGS
E-3 (i) 0.001412 0.o0 0.001420 0.o0 0.o0 0.o0
OVEUN CHAGE (j)
SURCHARGES
ACA(k)0.00190 0.001900
Issued: April i 1. 201 i
Effective: April 4, 201 1
Docket No. RPll-1986-000
Acceted: May 4, 2011
Foothlls System - Be Page 1 of2
t~ 'f~~~:~da
Foothills System. Be
TransCanada's - Foothils Be Transporttion Rates
2011 Rates Effive January 1, 2011
Seice Tar Rat Infon Purpses
ABlC to Klngsgat
$IGJlkm(Cdn)tlGJld
(Cdn)
i;lMcfld
(Cdn)
Ø/MMbtuld
(US)
FT Firm Servce. Zone 8
FT Rate
IT Interrptible Service. Zone 8
IT Rate
0.015821729 (Monthly)8.9 9.5 9.2
0.005732841 (Daily 9.8 10.5 10.2
1. For infòtitltipus. th maximum Shippers Haul Distnce us In the ShippmontlychargefOrSeic
calculation Is 170.7 km.
2. Rates are payable. In Canoolan doßars. and GJ unit&areìJse fo billin ptis. Mcf and MMbtu units are provided
fòrinfoatlon purpses only.
3. Converson Factrs below have been use to calculat th rates prvied fòr informatin purpses:
Cdn$US$
tfIGJ to tlMMBt
tl to tlMcf
1.016 - subjct 10 chnge (updated De 1,2010)
x 1.05056
at a heat value of 37.8 MJ/m3
4. All rates are based on 100 per cent load factor utilizon. The IT ree is 110 per cent of the FT ra.
5. Rates do not Includ G.S.T.
6. Inqiri rearding the Be Sysem may be direed to:
Brce Newrr
Phon: 1.403.920.559
Email: l:cenewllcmtrnsga.com
Minh Nguyn
htt://ww.transcaåd;comlcustomerexptessl2168.htm?prntres 1/22/2011
NOV A Gas Transmiion Ltd.Table of Ra, Tolls and Charges
Page I of 1
Strvae Qatt. ToU$ and Chrg
1. Rate Schedule Fl_RRefer to Aithment .. I" for applicable Fl-R Dema Rapêninthbiion a
thre yea t~ (PcePòint "B") &: Suthargefor eah Reipt Point
Aveiue FIrm Seric Receipt Pri (AFRP) $ 191.49Jl03m'
2. Rate Schedule Fl -RN Refer to Attachmet "1" f~r applicale Fl -RN Demand Rate per month &: Surhage
for eacb ReiÐl Point
3. Rate Schedule Pr-D Refer to Attchmt "2" for applicable Fl-D Dema Rae per month bas on a on
yea term (Pce Point "X') & Surhage for eah Grup 1 or Group 2 Delivery Point.
4. Rate Schedle STF
5. Rate Schedle Fl..DW
6. Rate Schedulé Fl-P
7 Rate Scheule LRS
8. Rate Scheule LRS-2
9. Rate Scedule LRS- 3
10.
11. Rae Scedule IT-D
12. Rae Schedule PCS
.,.,,;,,,,,.'::-''_0.'''''''''
Averae Fl-DDemañd Rate for Grop 1 DeüveryP~ints ($5.97/G1)
Fl-D Deman Rate for Group 2 Delivery Point i iT.141G1"Fl-D Deman Rate for GroUl) 3 Delive Points 2 N/A
STF Bid Prce "" Minimum of 100% of th. applicable Pr-D Dema Rate base on
a pne Year term (Pce Point "X') for ea Group I Deliver Point
Fl-DW Bid Prce ""Minimum of 125% of the applicale Fl-D Demand Rate. bas
on a the .yeterm (Prce Point "Y") fOr eah GruP 1 DeUver P"Oint
Refer to Attlt "3" Demad Rate pe monthCoTn JlS1-5 yea 10.646-10 yea 8.8915 ye 7l)720ve 7.08
LRS-ZRane month $$0.00
LRS-3 Dema Rae i:ll $ 129.5Slldn:l
Refer to Attcbmt. "I" for applicable n-R. Rate for eah Receiut Poin
Refer to Attachment "2" for aoolicaleIT-D Rate for eah Deliver Point
TbFCSChrge lsdeennneJnacrdan with Attacbmeut "1" to th applicable
ScbedteofSerce
::
13. Rate Scheule PT i¡=
50.01oim'/d
14. Rate Scedule OS
15. Ra Scheule CO2
9OCHOO-O
90-01001.1
Schedle No,
2011462247
2011462241
2011462238
2011462242
201146223
201146224
2011462240
2011462245
2011462252
2011462239
201146228
201146229
2011462246
2011462250
201146221
2011463220
200300522
:T
1
2
3
$~
$ 6ó.OO/d
Chrge
$ 27,00 I month
$ 7.00 I month
$ 20.00 I month
$ 3.00 I month
$ 1.00 I month
$ 32,00' motl
$ 1,00 I moth
$ 1.985.00 I mont
$ 3.00' month
$ 56.00' month
$ 135,00 I mont
$ 75,00' month$ i 1.00 I montl
$ 207.00 'mont
$ 204,00 I mouth
$ 392.00 I month
$ 83.333.00 I month
CQi :R($ItWmJ)
505.25
399.89
261.29
Rae for II Grup i Dever Points with lhe excepton of Albe-Monia Cod I. an Unii)'
f".O Sece at Grp 3 Deiver Points not avalable until th 1hiegrti Efecive Oi.
Effective Date:20ll (Amended Marh i, 2011)
Page 8.4
Westcost Eney Inc.
TOLL SCHEDULES. SERVE
APPENDIX A
DEMAND AND COMMODIT TOLLS
TRANSPRTATION SERVICE. SOUTHERN
Rnn Trasporttion Seice. Souttrn
T~PNG Inland Huntlng Kingal to
Seivce TéI Dellv PØlnt Delvry Ar DelivervArfl HumnQøn"*1 year 121.03 315.93 534.20 :l1fU1
2yers 111.50 30.72 518.64 211.92
3 years 113.98 297.52 50.08 205.56
4 years H2.8Ø 29.46 497.89 203.44
5 years or mo 111.63 291.39 C3 201.32
.. To .t: if'ed to th peitntage sinontofth applicbl toll spè InaSerloe Agrent fo
Enhanc T-8ou Seric
.. FÓ( Firm Tran$pQtlSeivoe . SOutm proVi by West pursnt to a FI SeAgteme
date April 15, 202 t:tw Wescoand )"eraseGa Inc.
Ptus th amount of ta on fuel gas cosumed In . opetion payable under th Motor FUel Tax Act
(Brish Columbia) and the Carbon Tax Act (Brish Columbi) Which is allocated to Shipper by
Westoo for ea day In the mon.
Demand Tolls
$/103m3/mo.
AOS and Interrptible Transpon Serce. Soutern
Commo!t Toll
$l103m3
TeMsnPNG Il1and Huntngdo Klngsvalf)to
lis Oellv!! Pollt DellVervAre Qe!v Ara Hunti~..NOvernt:r to Mar 5,281 13;186 23.310 9.525
ApliltoOcr 3.961 10.339 11.483 7.143
.. For AOS prde by We$tcpursnt to a Firm Seiv Agrement dmd Apri 15.,2002 be
Wesoost and Terasen Gas Inc.
Plus the amont of ta on ful gas consumed in operaon payae under the Motor Fuel Tax Act
(Brish Coumbia). and the Carb Tax Act (Brish Columba) Which Is alioctedto Shippr by
We$lcoast fo eaohday in the mont.
Effectve Date: Api11, 2011
Northwes :Ppele GP
FERC Ga Tar
FIrS R.vi Sheet No.5
FIft Revid Volume No. iSupeneg
Subste Originll Sheet No.5
STATEM OF RATES
Effective Rates Applicable to
Rate SchedulesTF-1, TF-2, '11-1, TFL-l and TIL-l
(Dollars per Dth)
Rate Schedule and
Tye of Rate
Base
Tariff Rate
Minimum Maimu AC (2 )
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide
15 Year Evergreen Ex.
25 Year Evergreen Exp.
Volumetric
(Large Customer)
System-Wide
15 Year Evergreen Ex¡.
.00000
.00000
. 00000
.00756
.00369
.37984
.38101
.36445
03000
.00369
.00190
.00190
25 Year Evergreen Ex. .00369 .00369
($mll Customer) (6) .00756Scheduled Overru .00756
. 00190 .00559
.67209 .00190
. 40984 . 00190
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Anual Overrun
Rate Schedule TI-lVolumetric (7)
Rate Schedule TFL-l (4) (5)
Reservation
Volumetric
Scheduled Overrun
Rate Schedule TIL-l
Volumetric
.00000
.00756
.00756
. 00756
.00756
.37984
.03000
.40984
.40984
.40984 .00190
CurrentlyEffective
Tariff Rate())Minimu Maimu
. 00000
.00000
. 00000 .36445
.00946.~.00559 ~J
.00559
.00946 .67399
.00946 .41174
.00000
.00756
.00756
.00756
.00946 .41174