20060929Revised application.pdf

Avista Corp.
1411 East Mission PO Box3727
Spokane, Washington 99220-3727
Telephone [phone]
Toll Free 800-727-9170
RECEIVED
20Gb SEP 29 ~M 8: 21
IDAHO PUG h; O'
UTILITIES COMIAISSI h
~~~'V'STA.
Corp.
September 28, 2006
State ofIdaho
Idaho Public Utilities Commission
Statehouse
Boise, Idaho 83720
Avo- 6 -0(;-
Attention: Ms. Jean D. Jewell
RE: TariffIPUC No. 27. Natural Gas Service
The Company hereby requests withdrawal of the Purchased Gas Cost Adjustment (PGA) filed with the
Commission on September 14 2006 as case number A VU-06-03.
In replacement of that filing the following tariff sheets are enclosed for filing with the Commission:
Ninth Revision Sheet 150 canceling Eighth Revision Sheet 150
Original Sheet 150A and
Sixth Revision Sheet 155 canceling Fifth Revision Sheet 155
This filing is a revised PGA, replacing the original PGA filing submitted by the Company and withdrawn as
noted above. The primary reason for this substitute filing is to revise the Company s proposed weighted average
cost of gas (W ACOG) to reflect a recent fall in wholesale natural gas prices.
If these tariff sheets are approved as filed, the Company s estimated annual natural gas revenue will decrease
approximately $2.8 million or about 3.4%. Ofthis amount, approximately $1.8 million of the decrease relates to
a decrease in the projected weighted average cost of gas (W ACOG) and approximately $1.0 million relates to a
decrease in the amortization rate related to the balance of deferred gas costs.
The average residential customer using 65 therms per month will see their monthly bill decrease
approximately $2.70 or about 3.4%, from $80.43 to $77.73 per month. The requested rate changes will have no
effect on the Company s net income.
These re-filed tariff sheets request an effective date of November 1 , 2006.
Also enclosed are an Application and workpapers that provide information supporting this proposed rate change.
If you have any questions regarding this filing, please feel free to call Craig Bertholf at [phone] or Brian
Hirschkom at [phone].
Sincerely:
~ ~,..
Kelly O. Norwood
Vice President
State and Federal Regulation
Enclosures
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that I have served Avista Corporation dba Avista Utilities' filing with Tariff
IPUC No. 27 Natural Gas Service by mailing a copy thereof, postage prepaid to the following:
Conley Ward
Givens Pursley LLP
601 W. Bannock St.
Boise , ID 83701-2720
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
Jean D Jewell , Secretary
Idaho Public Utilities Commission
472 W. Washington Street
Boise, ID 83720-5983
Edward A. Finklea
Cable Huston Benedict Haagensen &
Lloyd , LLP
1001 SW 5th , Suite 2000
Portland, OR 97204-1136
Coeur d'Alene Resort
Attn: William Reagan
Box 7200
Coeur d'Alene , ID 83816
Paul Franz
Interstate Concrete & Asphalt
845 West Kathleen Avenue
Coeur d'Alene, Idaho 83814
Stimson Lumber
O. Box 7400
Coeur d'Alene, ID 83816
Dated at Spokane, Washington this 28th day of September 2006.
Patty 01 ess
Rates Coordinator
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION OF
A VISTA UTILITIES FOR AN ORDER APPROVING
A CHANGE IN NATURAL GAS RATES AND CHARGES AVLJ
(;--oG-o3
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 and is in lieu of the Application filed with the Commission on September 14, 2006
as case number A VU-06-03 and withdrawn by letter dated September 28, 2006. In
replacement of that filing the Applicant requests that the proposed rates included in this
revised Purchased Gas Adjustment (PGA) filing be made effective on November 1 , 2006.
If approved as filed, the Company s annual revenue will decrease by approximately $2.
million or about 3.4%. In support of this Application, Applicant states as follows:
The name of the Applicant is A VISTA UTILITIES, a unit of A VISTA
CORPORATION, a Washington corporation, whose principal business office is 1411
East Mission A venue, Spokane, Washington, and is qualified to do business in the state
ofIdaho. Applicant maintains district 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
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 &
Governmental Affairs
A vista Utilities
O. Box 3727
Spokane, W A 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.
Ninth Revision Sheet 150 and Original Sheet 150A, which Applicant requests the
Commission approve, are filed herewith as Exhibit ". Also included in Exhibit "A" is
a copy of Ninth Revision Tariff Sheet 150 with the changes underlined and a copy of
Eighth Revision Tariff Sheet 150 with the proposed changes shown by lining over the
current language or amounts.
Additionally, Sixth Revision Sheet 155, which Applicant requests the
Commission approve, is also filed herewith as Exhibit ". Also included in Exhibit "
is a copy of Sixth Revision Tariff Sheet 155 with the changes underlined and a copy of
Fifth 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 ofthis 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 copy attached hereto as Exhibit
In addition, a separate notice to each Idaho gas customer will be included in their
current billing, a copy of which is attached hereto as Exhibit "B - 1"
VII.
The circumstances and conditions relied on for approval of Applicant's revised
rates are as follows: Applicant purchases natural gas for customer usage and transports it
over Williams Pipeline West (d.a. Northwest Pipeline Corporation), Gas Transmission
Northwest (GTN), TransCanada (Alberta), TransCanada (BC) and Westcoast 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
refunds or charges, miscellaneous revenue received from gas related transactions and the
revenue received from Cascade Natural Gas for the release of storage capacity at the
Jackson Prairie Storage Facility. However, the Company has recalled the release of
storage capacity at Jackson Prairie Storage Facility to Cascade Natural Gas effective
April 30 , 2007.
Applicant's filing of proposed tariff sheet 150 decreases the prospective natural
gas cost component included in the rates charged to firm sales customers by 2.547 cents
per thermo
In the Company s original PGA filing, it used forward natural gas prices as of
August 16th to price unhedged volumes for the forthcoming year (November 2006 -
October 2007). Since that time, forward prices for the forthcoming year have fallen over
$2.00 per decatherm (20 cents per therm). In this filing, the Company has used forward
gas prices as of September 21 st to price unhedged volumes. The result is a proposed
W ACOG of $.76244 reflected in this filing, as compared to a proposed W ACOG of
84712 reflected in the Company s original filing.
The Company has hedged approximately 60% of its estimated annual gas sales for
the forthcoming year. It will hedge an additional 20% of estimated sales within days of
this filing. The Company has not executed these hedges as of the date of this filing, as
forward market prices have continued to fall. At the first sign of an increase in forward
prices, the Company will execute these additional hedges. This hedge level
approximately 80% of estimated customer requirements is higher than the Company
planned level of approximately 66% prior to September. However, with the recent sharp
drop in forward prices, and the volatility of the wholesale natural gas market, the
Company believes it is prudent to execute these additional hedges at these lower prices.
The Company has discussed these additional hedges with the Commission Staff. Further
if forward prices for this winter continue to fall , the Company will consider executing
additional hedges beyond the 80% level. In that case, the Company will again contact the
Commission Staff prior to executing those additional hedges.
The Company continuously reviews its procurement strategy and makes changes
that it believes are appropriate. This past year, the Company has begun incorporating an
amount of longer-term hedges into its purchase portfolio to provide an additional degree
of rate stability in the future. Approximately 11 % of the total purchases for the next
year have been hedged at a three-year fixed price. The Company s plan is to continue
layering-in three-year fixed price hedges until these hedges represent one-third of the
portfolio going forward. At that point, the portfolio would consist of one-third hedged at
one year or less, one-third hedged for a period longer than one year, and one-third at
first-of-the-month index prices just prior to the month. This revised plan has been
incorporated into the Company s Risk Management Policy and provided to the
Commission Staff.
The proposed rates in this filing also incorporate the proposed rate increases filed
by the Company s two pipeline suppliers, Northwest Pipeline and Gas Transmission
Northwest. The proposed pipeline rates, while not approved, will begin being billed to
the Company on January 1 , 2007. While these pipeline rate increases are substantial, the
effect on the Company s proposed rates in this filing is completely mitigated by an
increase in the estimated revenue to be received from pipeline capacity releases. This
increase in estimated capacity release revenue is caused by an increase in the volumes
released, as compared to the level reflected in present rates, as well as the increase
related to the proposed pipeline rates.
In this filing, the Company is also proposing a change to the present amortization
rate(s), set forth under Schedule 155. This amortization rate is used to refund or
surcharge customers the difference between actual gas costs and projected gas costs
(from the last PGA filing) over the past year. The present amortization rate is a surcharge
of 5.027 cents per therm; the Company proposes to decrease this amortization rate to
3.420 cents per therm, a decrease of 1.607 cents per thermo The Company has an
estimated deferred gas cost balance of approximately $2.8 million as of October 31
2006 , reflecting higher gas costs than projected during the past year. The proposed
amortization rate of 3.420 cents per therm is expected to recover this balance over 12
months.
If the proposed decrease to tariff sheet 150 is approved, firm sales customers on
Schedules 101 111 , 112, 121 and 122 will see a rate decrease of2.547 cents per thermo
Interruptible sales customers on Schedules 131 and 132 will see a rate decrease of .701
cents per thermo
If the proposed decrease to tariff sheet 155 is approved, firm sales customers on
Schedules 101 , 111 and 121 will see a rate decrease of 1.607 cents per thermo
The average residential or small commercial customer using 65 therms per month
will see an estimated decrease of$2.70 per month or approximately 3.4%. The average
percentage changes for the various Schedules are shown on Exhibit ", page 2.
VIII.
Exhibit "C" attached hereto contains support for the rates proposed by Applicant
contained in Exhibit "
IX.
Applicant is requesting that Applicant's rates be approved to become effective on
November 1 , 2006. 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.
WHEREFORE, Applicant requests the Commission issue its Order finding
Applicant's proposed rate to be just, reasonable, and nondiscriminatory and to become
effective for all natural gas service on and after November 1 , 2006.
Dated at Spokane, Washington, this 28th day of September 2006.
A VISTA UTILITIES
?d;
~,..
..mJ
Kelly O. Norwood
Vice President, State and Federal Regulation
STATE OF WASHINGTON
) SSe
County of Spokane
Brian Hirschkorn, being first duly sworn, on oath deposes and says: that he is the
Manager of Retail Pricing of Avista Utilities; that he has read the above and foregoing
Application, knows the contents thereof, and believes the same to be true.
Brian Hirschkorn
Manager, Retail Pricing
SUBSCRIBED and sworn to before me this 28th day of September 2006.
~\,,\""'II""II"
s."'" "( OLS~ 1111",
:iii-
'"
~~ ........... ~(I':~s ....' .
. .".'. ~' ....
SO ~,, ...." n cIA
.... ,~~ ~.. ~
~ ""iC'.'
g !
o),otARY .,. \.
:: :~ '" ~ =:::: =:...
PU8\.\\", j
~ ~
~. ,st\ .Q..... -i:\'~~ f
'-"..
f;:1::J 22 r-;,
"'~t
:""'~~ ~
IIIII OF W~~ "/1/1/'111111\1\\\
Notary Public in and for the
State of Washington, residing in
Spokane.
A VIST A UTILITIES
Exhibit "
Proposed Tariff Sheets
September 28, 2006
I.P.C. No.
Ninth Revision Sheet 150
Canceling
Eighth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilities
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 rate adjustments imposed by the
Company s suppliers, to become effective as noted below.
RATE:
(a)The rates of firm gas Schedules 101 , 111 , 112, 121 and 122 are to be
increased by 30.626~ per therm in all blocks of these rate schedules.
The rates of interruptible Schedules 131 and 132 are to be increased by
31.096~ per thermo
(b)
(c)The rate for transportation under Schedule 146 is to be decreased by
OO.OOO~ 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:
Schedules 101
Schedules 111 and 112
Schedules 121 and 122
Schedules 131 and 132
Demand
853~
853~
853~
OOO~
Commodity
76.085~
76.085~
76.085~
76.085~
Total
83.938~
83.938~
83. 938~
76.085~
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.
Additional debits or credits for Pipeline refunds or charges, Pipeline capacity
release revenues and miscellaneous revenues or expenses directly related to the
Company s cost of purchasing gas to meet customer requirements will be recorded in the
Balancing Account.
Issued September 28, 2006 Effective November 1 , 2006
Issued by Avista Utilities
By
:1M r.n::JIY Norwood, Vice
President State & Federal Regulation
I.P.C. No.Original Sheet 150A 150
AVISTA CORPORATION
d/b/a Avista Utilities
SCHEDULE 150 - Continued
Deferred gas costs will be determined for individual customers served under
Schedules 112 , 122 , 132 and 146 , as well as for customers that switch to or from any of
these service schedules to another schedule. The deferred gas cost balance for these
customers will be based on monthly entries in the Balancing Account as described
above. The deferred gas cost balance for each customer will be eliminated by either, 1)
a lump-sum refund or surcharge, as applicable, or 2) an amortization rate per therm to
reduce the balance prospectively.
SPECIAL TERMS AND CONDITIONS:
The rates named herein are subject to increases as set forth in Schedule 158.
Issued September 28, 2006 Effective Novem ber 1 , 2006
Issued by Avista Utilities
By
;r/,.. rorrmJellY Norwood
, Vice President State & Federal Regulation
I.P.C. No.
Sixth Revision Sheet 155
Canceling
Fifth 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 , 111 and 121 are to be
increased by 3.420~ per therm in all blocks of these rate schedules.
The rate of interruptible gas Schedule 131 is to be increased by
3.420~ per thermo
(b)
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
Issued September 28 2006 Effective November 1 2006
Issued by Avista Utilities
?vt;
,.j
~IY Norwood, Vice President State & Federal Regulation
I.P.C. No.
Ninth Revision Sheet 150
Canceling
Eighth Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilities
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 rate adjustments imposed by the
Company s suppliers, to become effective as noted below.
RATE:
(a)The rates of firm gas Schedules 101 , 111 , 112, 121 and 122 are to be
increased by 30.626 per therm in all blocks of these rate schedules.
The rates of interruptible Schedules 131 and 132 are to be increased by
31.096 per thermo
(b)
(c)The rate for transportation under Schedule 146 is to be decreased by
OO.OOOi per thermo
WEIGHTED AVERAGE GAS COST:
e above rate chan es are based on the followin wei hted avera e cost of
er therm as of the effective date shown below:
Schedules 101
Schedules 111 and 112
Schedules 121 and 122
Schedules 131 and 132
Demand
853
853
853i
000i
Commodity
76.085
76.085i
76.085
76.085i
Total
83.938
83.938i
83.
76.085
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.
Additional debits or credits for Pipeline refunds or charges, Pipeline capacity
release revenues and miscellaneous revenues or expenses directly related to the
Company s cost of purchasing gas to meet customer requirements will be recorded in the
Balancing Account.
Issued September 28 2006 Effective November 1 , 2006
Issued by Avista Utilities
Kelly Norwood, Vice President State & Federal Regulation
I.P.C. No.
Sixth Revision Sheet 155
Canceling
Fifth 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 , 111 and 121 are to be
increased by 3.420 per therm in all blocks of these rate schedules.
The rate of interruptible gas Schedule 131 is to be increased by
3.420 per thermo
(b)
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
Issued September 28, 2006 Effective November 1 , 2006
Issued by Avista Utilities
Kelly Norwood, Vice President State & Federal Regulation
I.P.C. No.
Eighth Revision Sheet 150
Canceling
Seventh Revision Sheet 150
AVISTA CORPORATION
d/b/a Avista Utilities
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 rate adjustments imposed by the
Company s suppliers, to become effective as noted below.
RATE:
(a)The rates of firm gas Schedules 1D1 , 111 , 112, 121 and 122 are to be
increased by 173~per therm in all blocks of these rate schedules.
(b)The rates of interruptible Schedules 131 and 132 are to be increased by
707~per thermo
( c)The rate for transportation under Schedule 146 is to be decreased by
DD.DDDi per thermo
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.
Additional debits or credits for Pipeline refunds or charges, Pipeline capacity
release revenues and miscellaneous revenues or expenses directly related to the
Company s cost of purchasing gas to meet customer requirements will be recorded in the
Balancing account.
Deferred gas costs will be determined for individual customers served under
Schedules 112 , 122 , 132 and 146 , as well as for customers that switch to or from any of
these service schedules to another schedule. The deferred gas cost balance for these
customers will be based on monthly entries in the Balancing Account as described
above. The deferred gas cost balance for each customer will be eliminated by either, 1)
a lump-sum refund or surcharge, as applicable , or 2) an amortization rate per therm to
reduce the balance prospectively.
SPECIAL TERMS AND CONDITIONS:
The rates named herein are subject to increases as set forth in Schedule 158.
Issued October 28, 2005 Effective November 1 , 2005
Issued by Avista Utilities
~.... K::::;/orwOOd - Vice.President, State & Federal Regulation
I.P.C. No.
Fifth Revision Sheet 155
Canceling
Fourth 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 , 111 and 121 are to be
increased by 027~per therm In all blocks of these rate schedules.
The rate of interruptible gas Schedule 131 is to be increased by
867~per thermo
(b)
SOURCES OF MONTHLY RATE:
Changes in the monthly rates above result from amounts which have been
accumulated in the Purchase Gas Adjustment (PGA) Balancing Account as
described in Schedule 150 - Purchase Gas Cost Adjustment.
SPECIAL TERMS AND CONDITIONS:
The above Monthly Rate is subject to the provisions of Tax Adjustment Schedule
158.
Issued October 28 , 2005 Effective November 1 2005
Issued by Avlsta Utilities
By ::r Vice President, State & Federal Regulation
A VIST A UTILITIES
Exhibit "
W orkpapers
September 28 , 2006
Avista Utilities
State of Idaho
Calculation of Overall Rate Change
Actual Sch 150 Sch 150 Sch 155 Sch 155 Sch 155 Total Total
Annual Per Therm Annual Per Therm Annual Direct Chg Sch 155 Sch 150/155
Therms Inc .::Dec;:.Inc .::Dec;:.Inc .::Dec;:.Inc .::Dec;:..::Refunds;:.Inc .::Dec;:.Inc .::Dec;:.
Schedule 101 641 742 ($0.02547)($1 340,785)($0.01607)($845 953)($845,953)($2,186,738)
Schedule 111 856,234 ($0.02547)($378,388)($0.01607)($238,740)($238 740)($617,128)
Schedule 112 588 ($0.02547)($40)($40)
Schedule 121 895,245 ($0.02547)($48,272)($0.01607)($30,457)($30,457)($78 729)
Schedule 122 593,008 ($0.02547)($15,104)($15,104)
Schedule 131 ($0.00701)$0.00553
Schedule 132 535,085 ($0.00701)($3,751)($3,751)
Schedule 146 330,812
Coeur d'Alene Resort ($5,567)($5,567)($5 567)
St Joseph Hospital 426 506 $32,028 $32 028 $32 028
Coeur d'Alene Fiber Fuel $88 $88 $88
Idaho Asphalt
Imsamet
Interstate Concrete/Asphalt $29 086 $29,086 $29,086
Kootenai Medical
Lignetics
Merritt Brothers
Potlatch 209,602
Stimson Lumber (RA)($2 096)($2 096)($2,096)
Stimson Lumber (SW)
University of Idaho
112 489,822 ($1,786,340)($1 115 150)$53,539 ($1 061,611)($2 847 951)
Total Current Actual Annual Revenue $84,685 805
Percent of Increase .::Decrease;:.36%
Page 1
Avista Utilities
State of Idaho
Average Increase Per Customer
Sch Actual Average Average Average Present Total Proposed Total Estimated Estimated
Annual Monthly No. Of Mo. Usage Rate Present Rate Proposed Monthly Incr -::Decr;,.
Usage Usage Customers Per Cust.Cost Cost Incr -::Decr;,.Percentage
101 52,641 742 386,812 258 $1.18692 $77.15 $1.14538 $74.45
Basic Charge $3.$3.$3.
$80.43 $77. 73 ($2.70)36%
111 856 234 238 020 734 687
First 200 $1.16890 $233.$1.12736 $225.47
Next 800 $1.15070 $920.$1.10916 $887.
All Over 1 000 $1.04828 $720.$1.00674 $691 .
874.804.43 ($70.08)74%
112 588 132 132
First 200 $1.11863 $147.$1.09316 $144.
Next 800 $1.10043 $1.07496
All Over 1 000 $0.99801 $0.97254
$147.$144.($3.36)28%
121 895,245 157 937 19,742
First 500 $1.15779 $578.$1.11625 $558.
Next 500 $1.15051 $575.$1.10897 $554.49
Next 9 000 $1.04809 $9,432.$1.00655 $9,058.
All Over 10 000 $1.02931 $10,027.$0.98777 $9,622.
$20 614.$19,794.43 ($820.08)98%
122 593,008 49,417 709
First 500 $1.10752 $553.$1.08205 $541.
Next 500 $1.10024 $550.$1.07477 $537.
Next 9 000 $0.99782 980.$0.97235 $8,751.
All Over 10 000 $0.97904 $14 400.$0.95357 $14 026.
$24,484.$23,855.($629.33)57%
131 $0.91560 $0.91412
132 535,085 590 22,295 $0.88693 $19,774.$0.87992 $19,617.($156.28)79%
Page 2
Avista Utilities
Calculation of Idaho Proposed Rates
Sch Description Present Proposed Proposed Present Total
No.Tariff Schedule Schedule Schedule Proposed
Rate 150 155 191 (DSM)Rate
101 General $0.80066 $0.30626 $0.03420 $0.00426 $1.14538
111 Large General
First 200 $0.78317 $0.30626 $0.03420 $0.00373 $1.12736
Next 800 $0.76497 $0.30626 $0.03420 $0.00373 $1.10916
Over 1,000 $0.66255 $0.30626 $0.03420 $0.00373 $1.00674
112 Large General
First 200 $0.78317 $0.30626 $0.00373 $1.09316
Next 800 $0.76497 $0.30626 $0.00373 $1.07496
Over 1 000 $0.66255 $0.30626 $0.00373 $0.97254
121 Commercial
First 500 $0.77225 $0.30626 $0.03420 $0.00354 $1.11625
Next 500 $0.76497 $0.30626 $0.03420 $0.00354 $1.10897
Next 9,000 $0.66255 $0.30626 $0.03420 $0.00354 $1.00655
Over 10,000 $0.64377 $0.30626 $0.03420 $0.00354 $0.98777
122 Commercial
First 500 $0.77225 $0.30626 $0.00354 $1.08205
Next 500 $0.76497 $0.30626 $0.00354 $1.07477
Next 9,000 $0.66255 $0.30626 $0.00354 $0.97235
Over 10,000 $0.64377 $0.30626 $0.00354 $0.95357
131 Interruptible $0.56602 $0.31096 $0.03420 $0.00294 $0.91412
132 Interruptible $0.56602 $0.31096 $0.00294 $0.87992
146 Transportation $0.10976 $0.10976
Special Amortization Rates (Note 1)
St. Joseph Hospital $0.07600 $0.07600
Interstate Asphalt $0.27320 $0.27320
Note 1 - Customer has the option of the special amortization rate or a lump sum payment or refund
Page 3
Avista Utilities
Calculation of Idaho Present Rates
Sch Description Present Present Present Present Total
No.Tariff Schedule Schedule Schedule Present
Rate 150 155 191 (DSM)Rate
101 General $0.80066 $0.33173 $0.05027 $0.00426 $1.18692
111 Large General
First 200 $0.78317 $0.33173 $0.05027 $0.00373 $1.16890
Next 800 $0.76497 $0.33173 $0.05027 $0.00373 $1.15070
Over 1 000 $0.66255 $0.33173 $0.05027 $0.00373 $1.04828
112 Large General
First 200 $0.78317 $0.33173 $0.00373 $1.11863
Next 800 $0.76497 $0.33173 $0.00373 $1.10043
Over 1,000 $0.66255 $0.33173 $0.00373 $0.99801
121 Commercial
First 500 $0.77225 $0.33173 $0.05027 $0.00354 $1.15779
Next 500 $0.76497 $0.33173 $0.05027 $0.00354 $1.15051
Next 9,000 $0.66255 $0.33173 $0.05027 $0.00354 $1.04809
Over 10,000 $0.64377 $0.33173 $0.05027 $0.00354 $1.02931
122 Commercial
First 500 $0.77225 $0.33173 $0.00354 $1.10752
Next 500 $0.76497 $0.33173 $0.00354 $1.10024
Next 9,000 $0.66255 $0.33173 $0.00354 $0.99782
Over 10,000 $0.64377 $0.33173 $0.00354 $0.97904
131 Interruptible $0.56602 $0.31797 $0.02867 $0.00294 $0.91560
132 Interruptible $0.56602 $0.31797 $0.00294 $0.88693
146 Transportation $0.10976 $0.10976
Special Amortization Rates (Note 1)
St. Joseph Hospital $0.07324 $0.07324
Page 4
Avista Utilities
State of Idaho
Recap of Rate Changes
Previous Proposed Increase
Rate Rate oe::Decrease::.
Schedule 150
Schedule 101 $0.33173 $0.30626 ($0.02547)
Schedule 111 $0.33173 $0.30626 ($0.02547)
Schedule 112 $0.33173 $0.30626 ($0.02547)
Schedule 121 $0.33173 $0.30626 ($0.02547)
Schedule 122 $0.33173 $0.30626 ($0.02547)
Schedule 131 $0.31797 $0.31096 ($0.00701)
Schedule 132 $0.31797 $0.31096 ($0.00701)
Schedule 146
Schedule 155
Schedule 101 $0.05027 $0.03420 ($0.01607)
Schedule 111 $0.05027 $0.03420 ($0.01607)
Schedule 112
Schedule 121 $0.05027 $0.03420 ($0.01607)
Schedule 122
Schedule 131 $0.02867 $0.03420 $0.00553
Schedule 132
Schedule 146
Special Amortization Rates (Note 1)
St. Joseph Hospital $0.07324 $0.07600 $0.00276
Interstate Asphalt $0.27320 $0.27320
Combined Schedule 150 & 155
Schedule 101 $0.38200 $0.34046 ($0.04154)
Schedule 111 $0.38200 $0.34046 ($0.04154)
Schedule 112 $0.33173 $0.30626 ($0.02547)
Schedule 121 $0.38200 $0.34046 ($0.04154)
Schedule 122 $0.33173 $0.30626 ($0.02547)
Schedule 131 $0.34664 $0.34516 ($0.00148)
Schedule 132 $0.31797 $0.31096 ($0.00701)
Schedule 146
Special Amortization Rates (Note 1)
St. Joseph Hospital $0.07324 $0.07600 $0.00276
Interstate Asphalt $0.27320 $0.27320
Note 1 - Customer has the option of the special amortization rate or a lump sum payment or refund
Page 5
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

-

W
e
i
g
h
t
e
d

A
v
e
r
a
g
e

C
o
s
t

o
f

G
a
s
Fo
r
1
1
/
1
/
0
6
-
10
/
3
1
/
0
7
Da
i
l
y
Mo
n
t
h
l
y
All
o
c
a
t
e
d
Cu
r
r
e
n
t
Pr
o
p
o
s
e
d
2
M
o
n
t
h
s

o
f
10

M
o
n
t
h
s

o
f
We
i
g
h
t
e
d
Bil
l
i
n
g
Ra
t
e
Ra
t
e
To

I
d
a
h
o
Id
a
h
o
De
m
a
n
d
Co
m
m
o
d
i
t
y
Pi
p
e
l
i
n
e
Pi
p
e
l
i
n
e
Cu
r
r
e
n
t
Pr
o
p
o
s
e
d
Ra
t
e
No
t
e
s
De
t
e
r
m
i
n
a
n
t
s
Pe
r

M
M
B
t
u
Pe
r

T
h
e
r
m
To
t
a
l

C
o
s
t
(P
e
r
c
e
n
t
)
Co
s
t
s
Ra
t
e
Ra
t
e
Ra
t
e
Ra
t
e
El
f
.

1
/
1
/
0
7
NO
R
T
H
W
E
S
T

P
I
P
E
L
I
N
E
TF
-
2
D
e
m
a
n
d

C
h
a
r
g
e
96
4
,
80
0
$0
.
4
1
0
5
3
$1
.
2
4
8
7
0
$1
,
20
4
74
6
26
.
65
0
%
$3
2
1
,
06
5
$3
2
1
,
06
5
0.
2
7
7
6
0
43
7
1
2
55
5
2
0
37
1
2
0
0.
4
1
0
5
3
TF
-
2
T
r
a
n
s
p
o
r
t
a
t
i
o
n

C
h
a
r
g
e
87
1
00
0
$0
.
01
1
3
0
$0
.
00
1
1
3
$2
8
,
10
4
29
.
13
6
%
$8
,
18
8
18
8
03
0
0
0
00
7
5
6
06
0
0
0
07
5
6
0
01
1
3
0
SG
S
-

C
o
m
m
o
d
i
t
y

W
a
s
h
i
n
g
t
o
n
17
,
55
9
00
0
$0
.
58
8
4
8
$1
0
,
33
3
,
05
1
Id
a
h
o
31
2
00
0
$0
.
58
8
4
8
$4
,
30
2
93
7
10
0
.
00
0
%
30
2
,
93
7
$4
,
30
2
93
7
LS
-
1
D
e
m
a
n
d

D
e
l
i
v
e
r
a
b
i
l
i
t
y
64
0
,
00
0
$0
.
03
0
6
2
$0
.
09
3
1
4
$2
4
5
,
89
0
26
.
65
0
%
$6
5
,
53
0
$6
5
53
0
02
6
0
0
03
1
5
4
05
2
0
0
31
5
4
0
03
0
6
2
De
m
a
n
d

C
a
p
a
c
i
t
y
18
.
39
7
,
80
0
$0
.
00
3
9
1
$0
.
01
1
8
9
$2
1
8
,
75
0
26
.
65
0
%
$5
8
,
29
7
$5
8
,
29
7
00
3
3
2
00
4
0
3
00
6
6
4
04
0
3
0
00
3
9
1
Va
p
o
r
i
z
a
t
i
o
n
29
.
13
6
%
Co
m
m
o
d
i
t
y
29
.
13
6
%
TF
-
1
D
e
m
a
n
d

C
h
a
r
g
e
74
9
,
4
2
0
$0
.
4
1
0
5
3
$1
.
24
8
7
1
$2
0
,
91
5
,
16
8
26
.
65
0
%
$5
,
57
3
,
89
2
$5
,
57
3
,
89
2
27
7
6
0
0.
4
3
7
1
2
55
5
2
0
37
1
2
0
0.
4
1
0
5
3
En
d

U
s
e
r

C
a
p
a
c
i
t
y

R
e
l
e
a
s
e
s
21
6
,
00
0
$0
.
4
1
0
5
3
$1
.
24
8
7
1
$2
6
9
,
72
1
Co
m
m
o
d
i
t
y
16
3
,
81
8
,
00
0
$0
.
01
3
1
0
$0
.
00
1
3
1
$2
1
4
60
2
29
.
13
6
%
$6
2
,
52
6
$6
2
52
6

I
03
1
8
0
00
9
3
6
06
3
6
0
09
3
6
0
01
3
1
0
1
T
C
P
L

A
l
b
e
r
t
a

(
N
O
V
A
)

D
e
m
a
n
d
10
,
53
4
,
68
7
$0
.
11
0
3
1
$0
.
33
5
5
1
$3
,
53
4
,
4
9
3
26
.
65
0
%
$9
4
1
,
94
2
$9
4
1
94
2
1
T
C
P
L

A
l
b
e
r
t
a

(
N
O
V
A
)

D
e
m
a
n
d
59
5
,
17
6
$0
.
13
7
8
8
$0
.
4
1
9
3
9
$6
6
9
.
00
1
29
.
13
6
%
$1
9
4
92
0
$1
9
4
92
0
1
T
C
P
L

-

B
C
,

F
S
-
1
(
A
N
G
)
12
,
58
5
45
5
$0
.
06
2
6
8
$0
.
19
0
6
6
$2
,
39
9
,
54
3
26
.
65
0
%
$6
3
9
,
4
7
8
$6
3
9
,
47
8
27
7
6
0
0.
4
3
7
1
2
55
5
2
0
37
1
2
0
0.
4
1
0
5
3
1
G
T
N

D
e
m
a
n
d
10
,
58
3
,
22
0
$3
,
39
6
,
29
0
26
.
65
0
%
$9
0
5
11
1
$9
0
5
,
11
1
2
G
T
N

C
o
m
m
o
d
i
t
y
11
5
,
00
0
,
00
0
$0
.
00
0
0
3
$0
.
00
1
2
0
$1
3
8
,
00
0
29
.
13
6
%
$4
0
,
20
8
$4
0
,
20
8

I
00
0
0
1
3
00
0
0
3
7
00
0
0
2
6
0
0
00
0
3
7
00
0
0
3
1
W
e
s
t
c
o
a
s
V
D
u
k
e
29
,
71
3
,
4
3
0
$0
.
00
1
1
3
$0
.
03
4
4
4
$1
,
02
3
,
33
1
26
.
65
0
%
$2
7
2
,
71
8
$2
7
2
,
71
8
GA
S

S
O
U
R
C
E
S
Id
a
h
o

G
a
s

P
u
r
c
h
a
s
e
s
73
,
92
4
69
0
$0
.
76
2
4
4
$5
6
,
36
3
,
14
1
10
0
.
00
0
%
$5
6
,
36
3
,
14
1
$5
6
,
36
3
14
1
OT
H
E
R
Ca
p
a
c
i
t
y

R
e
l
e
a
s
e
s
($
9
.
97
4
00
0
)
26
.
65
0
%
($
2
65
8
,
00
0
)
(2
,
65
8
,
00
0
)
GR
I

F
u
n
d
i
n
g
$3
2
,
00
0
$3
2
00
0
1&
3
JP

R
e
l
e
a
s
e

t
o

C
a
s
c
a
d
e

N
a
t
u
r
a
l

G
a
s
($
3
2
0
00
0
)
26
.
65
0
%
($
8
5
,
28
0
)
(8
5
28
0
)
To
t
a
l
79
5
,
69
0
$9
4
96
2
,
76
8
$6
7
03
8
67
3
$6
,
22
9
,
67
3
$6
0
80
9
,
00
0
Es
t
i
m
a
t
e
d

T
h
e
r
m
s
79
.
33
0
,
72
6
79
,
92
2
,
05
2
Pr
o
p
o
s
e
d

W
A
C
O
G
$0
.
07
8
5
3
$0
.
76
0
8
5
Pr
e
s
e
n
1

G
a
s

C
o
s
t
s

i
n

R
a
t
e
s
$0
.
09
6
9
9
$0
.
76
7
8
6
Ra
t
e

C
h
a
n
g
e
($
0
.
02
5
4
7
)
($
0
.
01
8
4
6
)
($
0
.
00
7
0
1
)
To
t
a
l

T
h
e
r
m
s

P
u
r
c
h
a
s
e
d
18
2
,
4
5
1
.
84
1
75
,
01
6
,
25
9
25
7
,
4
6
8
,
10
0
Sc
h

1
0
1
Sc
h

1
1
1
Sc
h

1
1
2
Sc
h

1
2
1
Sc
h

1
2
2
Sc
h

1
0
1
Sc
h

1
1
1
Sc
h

1
1
2
Sc
h

1
2
1
Sc
h

1
2
2
Sc
h

1
3
1
Sc
h

1
3
2
No
t
e

1

-

B
a
s
e
d

o
n

5

d
a
y

p
e
a
k

s
t
u
d
y

(
4
/
3
0
/
0
6
)
26
.
65
0
%
No
t
e

2

-

C
o
m
m
o
d
i
t
y

A
l
l
o
c
a
t
i
o
n

P
e
r
c
e
n
t
a
g
e
I
W
a
s
h
i
n
g
t
o
n

Id
a
h
o

Sy
s
t
e
m

Al
l
o
c
a
t
i
o
n

P
e
r
c
e
n
t
a
g
e
70
.
86
4
%
29
.
13
6
%
10
0
.
00
0
%
No
t
e

3

-

J
a
c
k
s
o
n

P
r
a
i
r
i
e

R
e
l
e
a
s
e

t
o

C
a
s
c
a
d
e

N
a
t
u
r
a
l

G
a
s

h
a
s

b
e
e
n

r
e
c
a
l
l
e
d

e
f
f
e
c
t
i
v
e

4
/
3
0
/
0
7
Pa
g
e

6
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
Es
t
i
m
a
t
e
d

C
o
m
m
o
d
i
t
y

W
A
C
O
G
(B
a
s
e
d

o
n

8
/
1
6
/
0
6

F
o
r
w
a
r
d

P
r
i
c
e
s
)
Id
a
h
o
Tr
a
n
s
p
o
r
t
Le
s
s
:
To
t
a
l
To
t
a
l
Le
s
s
:
Ne
t
De
l
i
v
e
r
e
d
Fu
e
l
St
o
r
a
g
e
Id
a
h
o
Id
a
h
o
St
o
r
a
g
e

C
o
s
t
Id
a
h
o
Id
a
h
o
Vo
l
u
m
e
s
Vo
l
u
m
e
s
Wi
t
h
d
r
a
w
a
l
s
Vo
l
u
m
e
s
Go
m
m
.

C
o
s
t
s
Wi
t
h
d
r
a
w
a
l
s
Co
m
m
.

C
o
s
t
s
WA
C
O
G
No
v
e
m
b
e
r
20
0
6
86
1
21
0
16
8
,
63
0
10
,
02
9
,
84
0
22
2
,
4
5
9
$7
,
22
2
,
4
5
9
$0
.
72
0
1
0
De
c
e
m
b
e
r
12
,
38
7
67
0
21
1
83
0
(4
2
4
32
0
)
17
5
,
18
0
$9
,
79
3
,
30
8
(2
4
9
,
70
5
)
$9
,
54
3
,
60
3
$0
.
78
3
8
6
Ja
n
u
a
r
y
20
0
7
89
0
,
71
0
19
1
23
0
91
4
28
0
)
10
,
16
7
66
0
$1
0
,
12
3
,
24
6
71
4
98
4
)
$8
,
40
8
,
26
2
$0
.
82
6
9
6
Fe
b
r
u
a
r
y
67
1
11
0
14
8
,
16
0
69
8
,
16
0
)
12
1
11
0
69
9
,
58
4
58
7
80
3
)
$6
,
11
1
78
1
$0
.
85
8
2
6
Ma
r
c
h
99
7
52
0
12
1
39
0
00
4
91
0
)
11
4
00
0
$6
,
55
9
,
33
5
(5
9
1
36
8
)
$5
,
96
7
,
96
7
$0
.
83
8
9
0
Ap
r
i
l
87
2
,
91
0
10
1
08
0
(2
6
9
,
95
0
)
70
4
04
0
01
4
70
1
(1
5
8
,
85
7
)
$3
,
85
5
,
84
4
$0
.
67
5
9
8
Ma
y
4,
4
9
6
,
21
0
48
0
56
0
,
69
0
$3
,
18
7
69
1
$3
,
18
7
69
1
$0
.
69
8
9
5
Ju
n
e
13
9
,
89
0
59
,
4
0
0
19
9
,
29
0
34
6
,
92
6
34
6
,
92
6
$0
.
73
3
5
8
Ju
l
y
00
5
,
41
0
82
0
04
3
,
23
0
56
1
95
2
$1
,
56
1
95
2
$0
.
76
4
4
5
Au
g
u
s
t
07
6
,
4
6
0
39
,
10
0
11
5
,
56
0
61
8
,
91
3
$1
,
61
8
,
91
3
$0
.
76
5
2
4
Se
p
t
e
m
b
e
r
65
3
,
60
0
14
0
72
2
74
0
58
0
84
8
58
0
84
8
$0
.
69
3
2
7
Oc
t
o
b
e
r
86
9
,
37
0
10
1
98
0
97
1
35
0
$3
,
95
6
,
76
8
$3
,
95
6
,
76
8
$0
.
66
2
6
3
79
,
92
2
,
07
0
31
4
24
0
31
1
62
0
92
4
69
0
60
,
66
5
,
73
1
($
4
30
2
,
71
7
)
$5
6
,
36
3
,
01
4
$0
.
76
2
4
4
Pa
g
e

7
Avista Utilities
State of Idaho
Total Gas Costs
For 11/1/06 -10/31/07
Demand Commodity Total
Proposed Gas Costs
Schedules 101 - 122 $0.07853 $0.76085 $0.83938
Schedules 131 - 132 $0.76085 $0.76085
Present Gas Costs
Schedules 101 - 122 $0.09699 $0.76786 $0.86485
Schedules 131 - 132 $0.76786 $0.76786
Increase o:::Decrease:::-
Schedules 101 - 122 ($0.01846)($0.00701)($0.02547)
Schedules 131 - 132 ($0.00701)($0.00701)
Page 8
Avista Utilities
Calculation of Gas Transmission NW Corporation
FTS-FTS-FTS-FTS-Total
00177 00177 00178 002591
(Oct - Mar)(Apr - Sept)
MMBtu 823 000 20,782 000
Number of Effective Months
Annual MMBtu 328 938 180,000 249 384 300,000 058 322
Fixed Rate (Note 1)$1.306903 $1.518340 $1.412621 $1.412621
Mileage Rate (Note 1)$0.016230 $0.018740 $0.017486 $0.017486
Mileage 103.103.103.108.
Total Mileage Rate $1.674770 $1.933780 $1.804380 $1.893560
Fixed Annual Amount $429 890.$273 301.$352 285.$423,786.$ 1,479,262.
Annual Mileage Based Amount $550,895.49 $348,080.40 $449 983.$568,068.917 027.
Total Annual Amount $980 785.$621 381.$802 268.$991 854.396 290.
Note 1 - Rate based on two months at current rate and ten months at proposed rate, see following:
Gas Transmission NW , Third Revised Volume No. 1-
8th Revised
Sheet No.
(Current)
9th Revised
Sheet No.
(Proposed)
Total
Pro-Rated
Rate
Effective Months
Divide by 12 Months
Pro-Rated Fixed Rate (Per MMBtu)
049918
365
884028 $1.518340
147338 265283 1.412621
049918
365
884028 $1.518340
294676 012227 1 .306903
$0.000616
365
011212 $0.018740
003737 012493 016230
$0.000616
365
011212 $0.018740
001869 015617 017486
Page 9
Daily Fixed Rate Non Mileage
Annualize
Divide by 12 Months
Monthly Rate (Per MMBtu)
Effective Months
Divide by 12 Months
Pro-Rated Fixed Rate (Per MMBtu)
Daily Fixed Rate Non Mileage
Annualize
Divide by 12 Months
Monthly Rate (Per MMBtu)
Effective Months
Divide by 6 Months
Pro-Rated Fixed Rate (Per MMBtu)
Daily Mileage Per Mile (Oct - Mar)
Annualize
Divide by 12 Months
Monthly Rate (Per MMBtu)
Effective Months
Divide by 6 Months
Pro-Rated Fixed Rate (Per MMBtu)
Daily Mileage Per Mile (Annuals)
Annualize
Divide by 12 Months
Daily Mileage Per Mile (Annual)
Avista Utilities
TCPL BC (ANG) DemandNolumetric Calculation
Capacity
Decatherms
Annualized
FS-1 Firm Service Demand Rate
Tariff Schedule Tab 3, Page 2
Demand Rate (Canadian cents/GJ/Km/Month)
Convert to a daily rate
Convert to MMBtu
Convert to U.S. Dollars
Decatherms
92,239
117,519
209,758
Number of
Months
Annualized
Decatherms
553,432
705,113
1 ,258,545
$0.012454355541
* 12 Mos/365 Days
$0.0698945257
1 .055056
$0.0737426387
85%
$0.0626812429
Page 10
Avista Utilities
TCPL BC (NOVA) Demand Calculation
Effective 11/1/2006
Rate Schedule FT-
Demand Rate per month (C$)
Daily Demand (*12 mos/365 days)
Convert to GJ (/38.25)
Convert to MMBtu s (*055056)
Convert to U.S. Dollars
Daily per MMBtu
$3.
$0.1230
$0.129772
85%
$0.110306 $0.137880
Page 11
Avista Utilities
TCPL BC (NOVA) Demand Calculation
Rate Schedule FT-
Demand Rate per month (C$)
(10 cubed/m cubed)
Daily Demand (*12 mos/365 days)
Convert to GJ (/38.25)
Convert to MMBtu (*055056)
Convert to U.S. Dollars
$446.
$14.6887
$0.384017
$0.405159
85%
$0.344385
Page 12
Avista Utilities
State of Idaho - Weighted Average Cost of Gas
Estimated Transportation Therms/Revenue
NWP
Daily Annualized Demand Annual
Firm Volumes Rate Estimated
(Note 2)Revenue
Washington Transporters
Empire Health Services 000 000 $1.24871 $104 892
Eastern Washington University 000 000 24871 104 892
Sacred Heart 000 48,000 24871 59,938
Kaiser Trentwood (Note 1)24871
Total Washington 18,000 216,000 269,722
Idaho Transporters
Potlatch (Note 1)24871
University of Idaho (Note 1)24871
Total Idaho
Total Washington/Idaho 18,000 216,000 $269,722
Note 1 - These customers no longer have a Buy/Sell Arrangement but
are billed direct by NW Pipeline
Note 2 -From NWP Thirtieth Revised Sheet 5, Effective 10/1/05
Rate Schedule TF-, Large Customer, System-Wide (MMBtu)$0.27760
From NWP Proposed Thirty-First Revised Sheet 5, Effective 1/1/07 $0.43712
Rate Schedule TF-, Large Customer, System-Wide (MMBtu)
Annualize 365 365
Divide by 12 Months
Divide by 10 to get from MMBtu to Therms
Monthly Rate $0.84437 $1.32957
Effective Months
Divide by 12 Months
Pro-Rated Rate $ 0.14073 $1 .10798 $1.24871
Page 13
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

-

E
s
t
i
m
a
t
e
d

T
h
e
r
m

S
a
l
e
s
To
t
a
l
Sc
h

1
0
1
Sc
h

1
1
1
Sc
h

1
2
1
Sc
h

1
3
1
Es
t
.

S
a
l
e
s
Sc
h

1
4
6
Sc
h

1
4
7
Po
t
l
a
t
c
h
To
t
a
l
Th
e
r
m
s
Ja
n
u
a
r
y
20
0
7
97
4
81
7
60
7
24
1
27
0
,
28
5
38
,
36
7
89
0
,
71
0
34
7
15
7
29
3
,
53
2
14
0
,
37
5
67
1
77
4
Fe
b
r
u
a
r
y
7,
4
8
3
,
14
4
92
8
,
27
3
21
8
,
81
2
40
,
87
9
67
1
10
8
31
2
20
4
27
8
,
60
6
34
9
,
67
9
61
1
,
59
7
Ma
r
c
h
12
2
78
5
61
8
,
28
4
21
3
,
77
9
66
6
99
7
51
4
31
5
,
11
3
32
3
,
29
1
15
9
,
4
4
1
12
,
79
5
,
35
9
Ap
r
i
l
36
2
,
4
3
8
26
0
,
87
5
21
2
20
9
37
,
38
5
87
2
90
7
38
1
50
5
27
1
58
6
23
5
,
37
5
10
,
76
1
37
3
Ma
y
10
3
,
88
2
13
7
26
7
22
3
,
66
5
39
3
4,
4
9
6
,
20
7
42
6
,
4
1
7
25
4
89
5
23
8
,
50
0
9,
4
1
6
,
01
9
Ju
n
e
95
7
,
08
7
87
7
76
6
25
8
,
4
4
1
46
,
59
7
13
9
,
89
1
42
7
72
3
25
8
,
28
1
25
1
02
1
07
6
,
91
6
Ju
l
y
11
0
,
60
2
67
3
,
13
7
18
4
,
37
6
29
1
00
5
,
4
0
6
41
0
,
87
8
26
9
,
75
1
50
9
,
91
4
19
5
,
94
9
Au
g
u
s
t
17
5
,
01
2
69
4
34
7
15
1
49
8
55
,
60
3
07
6
,
4
6
0
38
8
,
00
4
26
2
14
2
34
9
,
14
2
07
5
,
74
8
Se
p
t
e
m
b
e
r
71
2
,
01
2
74
9
,
60
8
13
9
,
82
5
15
4
65
3
,
59
9
40
5
,
08
0
28
0
,
54
3
4,
4
4
3
,
00
0
78
2
,
22
2
Oc
t
o
b
e
r
36
5
,
84
8
26
8
,
61
2
18
2
90
0
52
,
01
2
86
9
,
37
2
45
8
,
93
5
27
6
,
31
5
29
8
,
54
1
10
,
90
3
,
16
3
No
v
e
m
b
e
r
20
0
6
73
0
,
84
0
80
2
,
4
5
7
21
3
,
92
7
11
3
,
98
3
86
1
20
7
41
9
,
83
2
19
9
,
61
3
96
4
15
1
14
,
4
4
4
80
3
De
c
e
m
b
e
r
99
2
10
4
14
7
20
9
20
5
,
36
2
99
6
12
,
38
7
,
67
1
41
0
21
6
19
6
,
86
3
89
4
04
7
16
,
88
8
,
79
7
60
,
09
0
,
57
1
16
,
76
5
,
07
6
2,
4
7
5
,
07
9
59
1

,
32
6
79
,
92
2
,
05
2
70
3
,
06
4
16
5
,
4
1
8
50
,
83
3
,
18
6
13
8
,
62
3
,
72
0
Es
t
i
m
a
t
e
d

L
o
s
s

F
a
c
t
o
r
10
2
.
15
5
%
Es
t
i
m
a
t
e
d

T
h
e
r
m
s

P
u
r
c
h
a
s
e
d
64
4
,
4
0
0
Id
a
h
o

C
o
m
m
o
d
i
t
y

P
e
r
c
e
n
t
a
g
e
29
.
13
6
%
Es
t
i
m
a
t
e
d

S
y
s
t
e
m

T
h
e
r
m
s

P
u
r
c
h
a
s
e
d
28
0
,
21
8
,
00
0
Pa
g
e

1
4
Avista Utilities
State of Idaho - Estimated Therms Purchased
Actual System
Purchases For 12
Months Ended
06-30-
Jackson Prairie Withdrawals
Washington
Idaho
12,132,506
908,414
Plymouth Withdrawals
Purchases Allocated to Washington
Purchases Allocated to Idaho
170,319,335
70,107 845
Firm Volumes
Gas Control'
Estimated
Therms
559,000
310,000
255,349,000
257,468,100 280,218,000
Page 15
Avista Utilities
State of Idaho
Recap of Changes To Schedule 150
Anticipated Effective Date 11/1/06
CENTS PER THERM Commodity Demand Charge Total
Schedule 101
Current Rate 31797 01376 33173
Proposed Incro::::Decr:;.(0.00701)(0.01846)(0.02547)
Proposed Rate 31096 (0.00470)30626
Schedule 111
Current Rate 31797 01376 33173
Proposed Incro::::Decr:;.(0.00701)(0.01846)(0.02547)
Proposed Rate 31096 (0.00470)30626
Schedule 112
Current Rate 31797 01376 33173
Proposed Incro::::Decr:;.(0.00701)(0.01846)(0.02547)
Proposed Rate 31096 (0.00470)30626
Schedule 121
Current Rate 31797 01376 33173
Proposed Incro::::Decr:;.(0.00701 )(0.01846)(0.02547)
Proposed Rate 31096 (0.00470)30626
Schedule 122
Current Rate 31797 01376 33173
Proposed Incro::::Decr:;.(0.00701)(0.01846)(0.02547)
Proposed Rate 31096 (0.00470)30626
Schedule 131
Current Rate 31797 31797
Proposed Incro::::Decr:;.(0.00701)(0.00701)
Proposed Rate 31096 31096
Schedule 132
Current Rate 31797 31797
Proposed Incro::::Decr:;.(0.00701 )(0.00701 )
Proposed Rate 31096 31096
Schedule 146
Current Rate
Proposed Incro::::Decr:;.
Proposed Rate
Page 16
Avista Utilities
State of Idaho
Calculation of Changes to Schedule 155
Current
Rate
Incr -=:Decr:::-
Proposed
Rate
Incr -=:Decr:::-
Total
Proposed
Incr -=:Decr:::-
Firm Customers, Schs 101, 111 & 121 $0.05027 $0.03420 ($0.01607)
Firm Customers, Schedules 112 & 122
Interruptible Customers, Schedules 131 $0.02867 $0.03420 $0.00553
Interruptible Customers, Schedules 132
Transportation Customers, Schedules 146
Special Amortization Rates (Note 1)
St. Joseph Hospital $0.07324 $0.07600 $0.00276
Interstate Asphalt $0.27320 $0.27320
Note 1 - Customer has the option of the special amortization rate or a lump sum payment or refund
Page 17
Avista Utilities
Idaho Gas Tracker
Calculation of New Amortization Rate
Total
All Firm All Sales Amortization
Customers Customers Rate
Schedule 101 ($0.03143)$0.06563 $0.03420
Schedule 111 ($0.03143)$0.06563 $0.03420
Schedule 112 $0.00000
Schedule 121 ($0.03143)$0.06563 $0.03420
Schedule 122 $0.00000
Schedule 131 ($0.03143)$0.06563 $0.03420
Schedule 132 $0.00000
Page 18
Avista Utilities
Idaho Gas Tracker
Unamortized Current
Deferrals Deferrals Total Adjustments Total
Note 1 Note 1
(Acct 191000)(Acct 191010)
All Firm Customers 505.(2,4 75,482.80)465,977.56)(2,465,977 .56)
All Sales Customers (442 556.74)630,628.188,071.188,071.
Coeur d'Alene Resort 567.44)567.44)(5,567.44)
Coeur d'Alene Fiber Fuel 87.87.87.
Idaho Asphalt
IMCa
Interstate Asphalt 15.29,070.29,086.29,086.
Kootenai Medical Center
Lignetics
Merritt Brothers
Potlatch
Stimson Lumber - River Avenue (1.86)094.27)096.13)096.13)
Stimson Lumber - Seltice Way
St. Joseph Hospital (5,685.31)713.027.32,027.
University of Idaho
(438 722.70)214 355.775,632.775 632.
Note 1 - Balance includes 7/05 - 8/06 actuals and 9/06 - 10/06 estimates
Page 19
Av
i
s
t
a

U
t
i
l
i
t
i
e
s
Id
a
h
o

G
a
s

T
r
a
c
k
e
r
Ca
l
c
u
l
a
t
i
o
n

o
f

A
m
o
r
t
i
z
a
t
i
o
n

R
a
t
e
Fi
r
m

C
u
s
t
o
m
e
r
s

(
S
c
h
e
d
u
l
e
s

1
0
1
,

1
1
1

&

1
2
1
)
Sc
h

1
0
1
Sc
h

1
1
1
Sc
h

1
2
1
To
t
a
l
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Th
e
r
m
s
Th
e
r
m
s
Th
e
r
m
s
Th
e
r
m
s
($
0
.
03
1
4
3
)
00
%
To

B
e
Am
o
r
t
i
z
e
d
(2
,
4
6
5
,
97
7
.
56
)
No
v
e
m
b
e
r
20
0
6
73
0
,
84
0
80
2
,
4
5
7
21
3
,
92
7
74
7
,
22
4
30
6
,
35
5
.
(5
,
78
2
.
00
)
(2
,
16
5
,
4
0
4
.
31
)
De
c
e
m
b
e
r
99
2
,
10
4
14
7
20
9
20
5
,
36
2
12
,
34
4
67
5
38
7
99
3
.
92
8
.
52
)
78
2
,
33
9
.
69
)
Ja
n
u
a
r
y
20
0
7
97
4
81
7
60
7
24
1
27
0
,
28
5
12
,
85
2
34
3
40
3
,
94
9
.
(3
,
95
0
.
91
)
38
2
,
34
1
.
4
6
)
Fe
b
r
u
a
r
y
7,
4
8
3
,
14
4
92
8
,
27
3
21
8
,
81
2
63
0
,
22
9
30
2
67
8
.
(3
,
07
7
.
51
)
08
2
74
0
.
87
)
Ma
r
c
h
12
2
78
5
61
8
,
28
4
21
3
,
77
9
95
4
84
8
25
0
,
02
0
.
39
4
.
33
)
(8
3
5
,
11
4
.
33
)
Ap
r
i
l
36
2
,
4
3
8
26
0
,
87
5
21
2
20
9
83
5
,
52
2
18
3
,
4
1
0
.
4
6
85
8
.
52
)
(6
5
3
,
56
2
.
39
)
Ma
y
10
3
,
88
2
13
7
26
7
22
3
,
66
5
4,
4
6
4
81
4
14
0
,
32
9
.
(1
,
4
5
8
.
4
9
)
(5
1
4
69
1
.
78
)
Ju
n
e
95
7
08
7
87
7
76
6
25
8
,
44
1
09
3
,
29
4
22
2
.
16
5
.
20
)
(4
1
8
,
63
4
.
75
)
Ju
l
y
11
0
,
60
2
67
3
,
13
7
18
4
37
6
96
8
,
11
5
85
7
.
(9
6
9
.
26
)
(3
5
7
,
74
6
.
16
)
Au
g
u
s
t
17
5
,
01
2
69
4
34
7
15
1
,
4
9
8
02
0
,
85
7
63
,
51
5
.
(8
1
4
.
97
)
(2
9
5
,
04
5
.
59
)
Se
p
t
e
m
b
e
r
71
2
01
2
74
9
60
8
13
9
,
82
5
60
1
,
4
4
5
11
3
,
19
3
.
4
2
(5
9
6
.
12
)
(1
8
2
,
4
4
8
.
29
)
Oc
t
o
b
e
r
36
5
,
84
8
26
8
,
61
2
18
2
90
0
81
7
36
0
18
2
83
9
.
(2
2
7
.
57
)
16
3
.
Pa
g
e

2
0
Av
i
s
t
a

U
t
i
l
i
t
i
e
s
Id
a
h
o

G
a
s

T
r
a
c
k
e
r
Ca
l
c
u
l
a
t
i
o
n

o
f

A
m
o
r
t
i
z
a
t
i
o
n

R
a
t
e
Sa
l
e
s

C
u
s
t
o
m
e
r
s

(
S
c
h
e
d
u
l
e
s

1
0
1
,
1
1
1
,
1
2
1

&

1
3
1
)
Sc
h

1
0
1
Sc
h

1
1
1
Sc
h

1
2
1
Sc
h

1
3
1
To
t
a
l
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Th
e
r
m
s
Th
e
r
m
s
Th
e
r
m
s
Th
e
r
m
s
Th
e
r
m
s
$0
.
06
5
6
3
00
%
To

B
e

Am
o
r
t
i
z
e
d
18
8
,
07
1
.
No
v
e
m
b
e
r
20
0
6
73
0
,
84
0
80
2
,
4
5
7
21
3
92
7
38
,
36
7
78
5
,
59
1
(6
4
2
22
8
.
34
)
16
7
.
55
8
,
01
0
.
De
c
e
m
b
e
r
99
2
10
4
14
7
20
9
20
5
,
36
2
40
,
87
9
38
5
,
55
4
(8
1
2
86
3
.
91
)
10
,
37
8
.
75
5
,
52
5
.
Ja
n
u
a
r
y
20
0
7
97
4
81
7
60
7
,
24
1
27
0
,
28
5
66
6
89
5
,
00
9
(8
4
6
29
9
.
4
4
)
33
0
.
91
7
55
7
.
Fe
b
r
u
a
r
y
7,
4
8
3
,
14
4
92
8
,
27
3
21
8
,
81
2
38
5
66
7
,
61
4
(6
3
4
,
4
8
5
.
51
)
50
0
.
28
9
,
57
2
.
Ma
r
c
h
12
2
,
78
5
61
8
,
28
4
21
3
,
77
9
39
3
98
6
,
24
1
(5
2
4
13
7
.
00
)
06
8
.
77
0
,
50
4
.
4
1
Ap
r
i
l
36
2
,
43
8
26
0
,
87
5
21
2
20
9
46
,
59
7
88
2
11
9
(3
8
6
,
04
3
.
4
7
)
94
3
.
38
8
,
4
0
4
.
Ma
y
10
3
,
88
2
13
7
26
7
22
3
,
66
5
29
1
50
2
10
5
(2
9
5
,
47
3
.
15
)
10
1
.
09
6
,
03
3
.
Ju
n
e
95
7
,
08
7
87
7
,
76
6
25
8
,
4
4
1
55
,
60
3
14
8
,
89
7
(2
0
6
,
66
2
.
11
)
2,
4
8
1
.
89
1
,
85
2
.
Ju
l
y
11
0
,
60
2
67
3
,
13
7
18
4
37
6
15
4
02
0
26
9
(1
3
2
59
0
.
25
)
06
3
.
76
1
,
32
6
.
4
6
Au
g
u
s
t
17
5
,
01
2
69
4
34
7
15
1
,
4
9
8
01
2
07
2
86
9
(1
3
6
,
04
2
.
39
)
1
,
73
3
.
62
7
,
01
7
.
Se
p
t
e
m
b
e
r
71
2
01
2
74
9
,
60
8
13
9
,
82
5
11
3
98
3
71
5
,
4
2
8
(2
4
3
,
84
3
.
54
)
26
2
.
38
4
,
4
3
6
.
Oc
t
o
b
e
r
36
5
,
84
8
26
8
,
61
2
18
2
90
0
99
6
86
0
35
6
(3
8
4
61
5
.
16
)
48
0
.
30
1
.
Pa
g
e

2
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
Ac
c
o
u
n
t

1
9
1
.
4
0
/
1
9
1
0
0
0

D
e
t
a
i
l
6/
3
0
/
0
5
7/
3
1
/
0
5
7/
3
1
/
0
5
8/
3
1
/
0
5
8/
3
1
/
0
5
9/
3
0
/
0
5
9/
3
0
/
0
5
10
/
3
1
/
0
5
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Fi
n
n

C
u
s
t
o
m
e
r
s
65
9
,
66
3
.
8,
4
1
2
.
77
3
.
67
0
,
84
9
.
90
1
.
79
0
.
68
0
,
54
2
.
30
0
.
80
8
.
69
2
,
65
1
.
4
5
18
,
4
0
2
.
83
6
.
All

S
a
l
e
s

C
u
s
t
o
m
e
r
s
(4
9
3
,
68
4
.
71
\
(7
2
34
6
.
18
8
3
.
08
\
(5
6
6
,
91
3
.
15
9
,
35
0
.
4
5
(9
9
4
.
16
2
7
25
8
.
(7
9
,
98
2
.
31

\
11
.
10
2
.
(7
0
8
,
34
3
.
(1
5
8
,
25
5
.
31
2
.
4
5
CD
A

A
s
p
h
a
l
t
CD
A

F
i
b
e
r

F
u
e
l
CD
A

R
e
s
o
r
t
(2
.
16
\
(2
.
16
)
12
.
16
\
(2
.
Hu
o
h
e
s

G
r
e
e
n
h
o
u
s
e
Id
a
h
o

A
s
p
h
a
l
t
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
o
n
e
t
i
c
s
Ril
e
v

C
r
e
e
k

L
u
m
b
e
r
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

-

D
e
A
n
n
o
n
d
Sti
m
s
o
n

L
u
m
b
e
r

-

A
t
l
a
s
10
.
10
.
(0
.
0
7
10
.
Un
i
v
e
r
s
i
t
Y

o
f

I
d
a
h
o
SI
.

J
o
s
e
p
h
51
2
.
16
1
.
24
.
69
7
.
11
6
.
24
.
83
8
.
24
.
86
3
.
4
9
24
.
7
7
To
t
a
l

A
c
c
t

1
9
1
.
18
0
,
48
9
.
16
3
,
77
1
.
91
4
.
11
8
63
1
.
15
2
33
2
.
82
0
.
06
8
,
11
9
.
(7
0
,
68
1
.
73
0
.
4
9
99
9
,
16
8
.
(1
3
9
,
85
2
.
4
1
54
8
.
Pa
g
e

2
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
Ac
c
o
u
n
t

1
9
1
.
40
/
1
9
1
0
0
0

D
e
t
a
i
l
Ad
j
u
s
t
m
e
n
t
To

M
a
t
c
h

D
e
f
10
/
3
1
/
0
5
Tr
a
c
k
e
r
PG
A

D
i
r
e
c
t
11
/
3
0
/
0
5
11
/
3
0
/
0
5
Wi
t
h

R
e
v
e
n
u
e
12
/
3
1
/
0
5
12
/
3
1
/
0
5
1/
3
1
/
0
6
Ba
l
a
n
c
e
Tr
a
n
s
f
e
r
Re
f
u
n
d
s
/
C
h
o
s
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Cv
c
l
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Fir
m

C
u
s
t
o
m
e
r
s
71
3
.
89
0
.
11
9
0
,
56
0
.
4
4
11
8
2
,
4
3
9
.
38
6
.
34
3
,
27
7
.
10
,
71
7
.
12
7
3
,
65
6
.
25
\
02
8
.
08
2
36
7
.
4
3
12
0
9
,
70
7
.
44
3
.
All

S
a
l
e
s

C
u
s
t
o
m
e
r
s
(8
6
7
.
91
1
.
46
1
57
9
.
12
4
2
15
4
.
2,4
5
4
.
35
3
.
96
7
.
13
6
3
,
22
8
.
95
3
.
99
2
69
3
.
12
7
8
34
7
.
99
\
13
3
.
CD
A

A
s
p
h
a
l
t
CD
A

F
i
b
e
r

F
u
e
l
12
4
.
(1
2
4
.
CD
A

R
e
s
o
r
t
12
.
10
.
60
)
Hu
o
h
e
s

G
r
e
e
n
h
o
u
s
e
Id
a
h
o

A
s
p
h
a
l
t
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t
18
,
52
6
.
(1
8
.
52
7
.
15
.
4
4
15
.
15
.
4
7
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
a
n
e
t
i
c
s
Ril
e
v

C
r
e
e
k

L
u
m
b
e
r
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

-

D
e
A
r
m
o
n
d
23
4
.
23
4
.
11
.
(1
.
86
\
(1
.
86
\
St
i
m
s
o
n

L
u
m
b
e
r

-

A
t
l
a
s
(0
.
0
7
12
.
11
2
.
69
\
(0
.
Un
i
v
e
r
s
i
t
v

o
f

I
d
a
h
o
SI
.

J
o
s
e
p
h
88
8
.
15
,
94
6
.
51
.
30
,
88
6
.
13
,
64
5
.
48
.
28
9
.
'3
,
59
7
.
63
.
To
t
a
l

A
c
c
t

1
9
1
.
4
0
86
0
,
86
5
.
30
3
,
39
5
.
'1
6
,
4
2
7
.
52
\
(4
2
4
59
4
.
90
6
.
72
8
,
14
5
.
10
,
71
7
.
16
4
0
,
52
9
.
03
1
.
10
2
,
36
3
.
(4
9
1
65
3
.
64
1
.
Pa
g
e

2
3
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
Ac
c
o
u
n
t

1
9
1
.
40
/
1
9
1
0
0
0

D
e
t
a
i
l
1/3
1
/
0
6
2/
2
8
/
0
6
2/
2
8
/
0
6
3/
3
1
/
0
6
3/
3
1
/
0
6
4/
3
0
/
0
6
4/
3
0
/
0
6
5/
3
1
/
0
6
5/
3
1
/
0
6
6/
3
0
/
0
6
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
Fir
m

C
u
s
t
o
m
e
r
s
87
5
,
10
3
.
(2
0
7
69
2
.
92
8
.
66
9
,
33
9
.
4
1
11
8
2
,
54
7
.
1,4
4
5
.
48
8
23
7
.
11
0
6
,
85
5
.
08
7
.
38
2
,
4
6
9
.
4
2
16
3
,
01
9
.
87
7
.
4
0
32
0
,
32
7
.
(4
6
95
8
.
4
6
Al
l

S
a
l
e
s

C
u
s
t
o
m
e
r
s
71
6
,
4
7
9
.
(2
7
5
,
67
3
.
1,4
4
6
.
44
2
25
2
.
12
4
2
,
29
7
.
4
4
1
80
2
.
20
0
75
8
.
11
4
1
83
0
.
32
4
.
25
2
.
4
7
18
3
64
7
.
43
.
12
4
35
1
.
(6
2
,
32
8
.
CD
A

A
s
o
h
a
i
t
CD
A

F
i
b
e
r

F
u
e
l
CD
A

R
e
s
o
r
t
Hu
Q
h
e
s

G
r
e
e
n
h
o
u
s
e
Id
a
h
o

A
s
o
h
a
l
t
In
t
e
r
s
t
a
t
e

A
s
o
h
a
l
t
15
.
15
.
15
.
15
.
15
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
o
n
e
t
i
c
s
Ri
l
e
v

C
r
e
e
k

L
u
m
b
e
r
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

-

D
e
A
r
m
o
n
d
11
.
11
.
86
\
11
.
86
\
11
.
11
.
St
i
m
s
o
n

L
u
m
b
e
r

-

A
t
l
a
s
Un
i
v
e
r
s
i
t
v

o
f

I
d
a
h
o
SI
.

J
o
s
e
p
h
23
,
75
5
.
78
2
.
55
.
02
8
.
12
,
96
4
.
32
'
48
.
18
,
11
3
.
13
,
09
3
.
41
.
4
2
15
.
06
1
.
71
0
.
34
.
12
,
38
4
.
(2
,
27
6
.
4
5
To
t
a
l

A
c
c
t

1
9
1
.
4
0

61
5
35
1
.
14
8
6
,
14
7
.
3,
4
3
0
.
13
2
63
5
.
14
2
7
,
80
8
.
29
6
.
70
7
,
12
3
.
12
5
1
77
9
.
34
\
1,
4
5
3
.
45
6
.
79
6
.
11
4
9
,
37
7
.
95
5
.
30
8
.
37
4
.
11
1
1
,
56
3
.
Pa
g
e

2
4
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
Ac
c
o
u
n
t

1
9
1
.
4
0
/
1
9
1
0
0
0

D
e
t
a
i
l
ES
T
I
M
A
T
E
D
ES
T
I
M
A
T
E
D
ES
T
I
M
A
T
E
D
ES
T
I
M
A
T
E
D
6/
3
0
/
0
6
7/
3
1
/
0
6
7/
3
1
/
0
6
8/3
1
/
0
6
8/
3
1
/
0
6
9/3
0
/
0
6
9/
3
0
/
0
6
10
/
3
1
/
0
6
10
/
3
1
/
0
6
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Am
o
r
t
i
z
a
t
i
o
n
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Fi
n
n

C
u
s
t
o
m
e
r
s
74
2
.
27
4
,
11
0
.
13
7
39
0
.
63
8
.
23
7
35
9
.
13
9
,
55
3
.
54
3
.
19
8
34
9
.
16
8
,
07
8
.
41
0
.
13
0
,
68
1
.
11
2
1
35
0
.
79
\
17
5
.
50
5
.
Al
l

S
a
l
e
s

C
u
s
t
o
m
e
r
s
11
3
8
.
18
6
,
81
8
.
14
9
62
8
.
12
7
9
.
11
3
6
,
72
6
.
15
2
50
0
.
14
0
7
.
4
5
18
9
,
63
4
.
19
0
,
36
2
.
15
8
7
.
12
8
0
58
3
.
25
'
11
6
1
07
0
.
69
\
19
0
2
.
14
4
2
,
55
6
.
CD
A

A
s
p
h
a
l
t
CD
A

F
i
b
e
r

F
u
e
l
CD
A

R
e
s
o
r
t
Hu
o
h
e
s

G
r
e
e
n
h
o
u
s
e
Id
a
h
o

A
s
o
h
a
l
t
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t
15
.
15
.
15
.
15
.
15
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Lio
n
e
t
i
c
s
Ri
l
e
v

C
r
e
e
k

L
u
m
b
e
r
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

-

D
e
A
n
n
o
n
d
11
.
11
.
11
.
8
6
11
.
11
.
St
i
m
s
o
n

L
u
m
b
e
r

-

A
t
l
a
s
Un
i
v
e
r
s
i
t
v

o
f

I
d
a
h
o
SI
.

J
o
s
e
p
h
28
.
10
,
13
5
.
76
6
.
23
.
39
3
.
11
,
65
6
.
18
.
75
5
.
87
9
.
88
5
.
56
5
.
15
.
15
.
68
5
.
31
\
To
t
a
l

A
c
e
!

1
9
1
.
4
0
63
1
.
4
8
19
7
44
2
.
18
8
,
78
4
.
38
2
.
10
9
,
03
9
.
19
3
,
71
0
.
4
4
15
5
.
4
6
15
,
4
8
4
.
11
6
4
,
32
0
.
11
6
6
.
69
\
11
4
9
,
00
2
.
12
8
8
,
98
6
.
17
3
3
.
14
3
8
,
72
2
.
Pa
g
e

2
5
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

19
1
.
4
1
/
1
9
1
0
1
0
F:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
l
P
a
g
e
A
Ba
l
a
n
c
e
7/
3
1
1
0
5
7/
3
1
/
0
5
Ca
s
c
a
d
e
7/
3
1
/
0
5
In
t
e
r
e
s
t
Ba
l
a
n
c
e
8/
3
1
/
0
5
8/
3
1
/
0
5
Ca
s
c
a
d
e
8/
3
1
/
0
5
In
t
e
r
e
s
t
Ba
l
a
n
c
e
6/
3
0
/
0
5
Co
m
m
o
d
i
t
y
De
m
a
n
d
Re
v
e
n
u
e
Of
f
-
Sy
s
t
e
m
7/
3
1
/
0
5
Co
m
m
o
d
i
t
y
De
m
a
n
d
Re
v
e
n
u
e
Of
f
-
Sy
s
t
e
m
8/
3
1
/
0
5
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Ca
p
.

R
e
i
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Ca
p
.

R
e
i
CD
A

R
e
s
o
r
t
(0
.
60
)
(0
.
60
)
(0
.
60
)
CD
A

F
i
b
e
r

F
u
e
l
12
4
.
24
.
(1
.
05
)
(1
1
.
01
)
13
7
.
7.
4
7
23
.
(1
.
06
)
(1
2
.
28
)
15
5
.
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d

p
o
i
n
t

52
6
.
30
0
.
31
.
85
8
.
56
9
.
33
.
21
,
4
6
1
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
23
4
.
00
)
33
8
.
00
9
.
(4
3
.
50
)
(4
5
6
.
65
)
(3
.
00
)
38
9
.
4
2
)
(2
.
30
)
39
1
.
72
)
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
12
.
12
.
12
.
St
.

J
o
s
e
p
h
94
6
.
53
7
.
27
.
51
0
.
45
8
.
31
.
00
0
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fir
m

C
u
s
t
o
m
e
r
s
(1
9
0
,
56
0
.
4
4
)
33
9
25
7
.
(1
4
61
4
.
85
)
(1
5
3
,
4
2
9
.
82
)
(1
7
4
.
92
)
(1
9
52
2
.
36
)
32
7
35
3
.
(1
4
65
8
.
34
)
(1
7
0
37
6
.
4
8
)
86
.
12
2
88
2
.
Sa
l
e
s

C
u
s
t
o
m
e
r
s
46
1
57
9
.
50
3
.
12
2
.
49
8
20
5
.
31
7
12
9
.
42
3
.
81
9
75
8
.
30
3
39
5
.
68
0
.
34
0
29
1
.
(1
4
65
9
.
4
0
)
(1
5
3
89
7
.
4
8
)
00
2
.
51
2
81
3
.
4
6
32
4
16
3
.
32
7
37
7
.
(1
4
65
9
.
4
0
)
(1
7
0
38
8
.
76
)
57
1
.
98
3
87
8
.
Pa
g
e

2
6
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
.
4
1
/
1
9
1
0
1
0
F:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
)
9/
3
0
/
0
5
10
/
3
1
/
0
5
9/
3
0
/
0
5
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
10
/
3
1
/
0
5
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Tr
a
c
k
e
r
11
/
3
0
/
0
5
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
9/
3
0
/
0
5
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
10
/
3
1
/
0
5
Tr
a
n
s
f
e
r
Co
m
m
o
d
i
t
y
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
De
f
e
r
r
a
l
CD
A

R
e
s
o
r
t
(0
.
60
)
10
,
4
4
3
.
(2
4
.
64
)
(6
.
11
)
10
,
4
2
0
.
CD
A

F
i
b
e
r

F
u
e
l
(1
.
05
)
16
2
.
(4
.
26
)
(1
.
06
)
15
8
.
(1
2
4
.
59
)
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d

p
o
i
n
t

70
0
.
4
7
47
.
20
9
.
01
2
.
66
.
28
7
.
(1
8
52
6
.
92
)
85
2
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
34
5
.
20
3
.
(4
2
.
12
)
(1
.
04
)
11
3
.
35
.
(1
7
0
.
13
)
(4
2
.
17
)
(6
2
.
33
)
23
4
.
73
.
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
12
.
12
.
(1
2
.
76
)
St
.

J
o
s
e
p
h
15
,
64
5
.
48
.
69
3
.
4
9
10
,
4
4
3
.
69
.
20
7
.
(1
5
94
6
.
50
)
16
,
4
9
5
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fir
m

C
u
s
t
o
m
e
r
s
68
9
.
4
5
(1
4
61
6
.
23
)
25
1
.
17
9
20
7
.
(5
8
94
8
.
57
)
(1
4
61
0
.
06
)
23
7
.
10
5
88
6
.
19
0
56
0
.
4
4
Sa
l
e
s

C
u
s
t
o
m
e
r
s
07
8
70
9
.
59
7
.
90
4
06
5
.
15
8
60
6
.
7,
4
7
2
.
07
0
14
4
.
(2
,
4
6
1
57
9
.
62
)
61
1
22
9
.
10
9
,
4
0
2
.
89
8
.
(1
4
65
9
.
4
0
)
94
3
.
15
5
46
3
.
18
8
54
2
.
(5
9
,
14
7
.
60
)
(1
4
65
9
.
4
0
)
85
4
.
27
8
,
05
3
.
30
3
,
39
5
.
35
)
63
5
65
0
.
Pa
g
e

2
7
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
.
4
1
/
1
9
1
0
1
0
F
:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
l
11
/
3
0
/
0
5
12
/
3
1
/
0
5
1/
3
1
/
0
6
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
11
/
0
5

C
o
m
m
.
12
/
3
1
/
0
5
11
/
0
5

D
e
m
a
n
d
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
11
/
3
0
/
0
5
Co
r
r
e
c
t
i
o
n
Co
m
m
o
d
i
t
y
Co
r
r
e
c
t
i
o
n
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
12
/
3
1
/
0
5
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
CD
A

R
e
s
o
r
t
17
.
43
8
.
4

7
06
6
.
(9
8
1
.
61
)
(1
7
.
77
)
22
.
4
5
52
7
.
73
1
.
CD
A

F
i
b
e
r

F
u
e
l
(2
9
.
54
)
(1
.
06
)
86
.
(5
9
.
92
)
(1
.
08
)
29
.
12
0
.
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d

p
o
i
n
t

49
.
4
8
33
,
66
1
.
56
.
33
,
71
7
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
17
9
.
63
)
(4
2
.
28
)
02
5
.
3.
4
4
54
1
.
(2
,
52
5
.
35
)
(4
5
.
71
)
01
0
.
82
7
.
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
St
.

J
o
s
e
p
h
65
.
82
1
.
77
5
.
39
7
.
86
.
08
1
.
90
2
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fi
r
m

C
u
s
t
o
m
e
r
s
(4
0
7
76
1
.
4
9
)
(1
4
61
6
.
06
)
14
2
.
(1
2
5
78
9
.
01
)
18
8
.
4
2
(8
0
6
29
0
.
56
)
(1
4
59
4
.
84
)
(8
9
1
.
90
)
(9
4
5
37
7
.
89
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
52
3
.
22
6
31
7
.
12
3
,
13
6
.
48
4
05
7
.
15
4
.
84
3
66
5
.
53
1
18
1
.
(4
0
8
97
0
.
66
)
(1
4
65
9
.
4
0
)
80
1
.
19
3
,
4
8
0
.
4
0
12
3
91
5
.
50
3
14
9
.
4
7
19
4
.
(8
0
9
,
85
7
.
44
)
(1
4
65
9
.
4
0
)
9,
4
3
1
.
00
7
65
4
.
4
9
55
4
76
3
.
Pa
g
e

2
8
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
.
4
1
/
1
9
1
0
1
0
F:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
l
1/
3
1
/
0
6
2/
2
8
/
0
6
2/
2
8
/
0
6
3/
3
1
/
0
6
3/
3
1
/
0
6
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
1/
3
1
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
2/
2
8
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
CD
A

R
e
s
o
r
t
16
1
.
4
9
)
(3
1
.
38
)
50
.
11
7
.
(6
3
7
.
13
)
35
4
.
32
)
(4
0
.
08
)
57
.
14
3
.
04
9
.
78
)
38
6
.
72
)
(4
8
.
74
)
52
.
CD
A

F
i
b
e
r

F
u
e
l
(4
1
.
68
)
(1
.
13
)
10
6
.
10
7
.
(0
.
36
)
(1
9
.
93
)
(0
.
70
)
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d

p
o
i
n
t

84
.
80
2
.
(2
1
.
81
)
84
.
4
8
86
4
.
84
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
91
3
.
33
)
(5
1
.
70
)
17
.
89
0
.
(2
7
0
.
93
)
68
0
.
33
)
(4
9
.
72
)
22
.
91
1
.
(3
4
7
.
65
)
17
6
.
01
)
(4
1
.
33
)
17
.
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
St
.

J
o
s
e
p
h
14
6
.
12
9
.
(6
0
8
.
33
)
15
4
.
67
5
.
(9
1
3
.
03
)
15
3
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fi
r
m

C
u
s
t
o
m
e
r
s
(5
3
9
,
4
5
3
.
62
)
(1
4
57
5
.
19
)
05
5
.
97
)
50
2
46
2
.
67
)
(4
9
2
36
8
.
4
2
)
(1
4
56
9
.
60
)
38
9
.
82
)
01
3
79
0
.
51
)
(4
1
4
51
6
.
88
)
(1
4
56
8
.
63
)
57
0
.
82
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
19
,
02
3
.
39
3
87
0
.
(1
5
1
,
4
5
2
.
98
)
79
5
.
26
3
21
2
.
(2
1
9
37
3
.
92
)
20
,
38
3
.
(5
4
2
57
0
.
12
)
(1
4
65
9
.
4
0
)
26
6
.
02
1
,
4
5
4
.
(1
5
2
99
1
.
18
)
(4
9
5
,
4
0
3
.
07
)
(1
4
65
9
.
4
0
)
16
,
72
4
.
37
5
,
12
5
.
(2
2
1
68
4
.
74
)
(4
1
7
09
9
.
54
)
(1
4
65
9
.
4
0
)
12
1
.
Pa
g
e

2
9
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
.
4
1
/
1
9
1
0
1
0
F:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
l
4/
3
0
/
0
6
4/
3
0
/
0
6
5/
3
1
/
0
6
5/
3
1
/
0
6
6/
3
0
/
0
6
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
3/
3
1
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
4/
3
0
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
5/
3
1
/
0
6
De
f
e
r
r
a
l
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
CD
A

R
e
s
o
r
t
71
0
.
50
1
.
09
)
(7
6
8
.
17
)
(5
8
.
18
)
42
.
14
,
4
2
5
.
74
6
.
05
)
82
.
(6
5
.
05
)
31
.
4
0
72
8
.
4
4
98
9
.
88
)
CD
A

F
i
b
e
r

F
u
e
l
86
.
2
5
86
.
4
7
86
.
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d
p
o
i
n
t
94
9
.
(0
.
82
)
84
.
03
3
.
(5
8
.
52
)
85
.
06
0
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
36
4
.
4
0
(7
,
7
1
9
.
95
)
(6
5
5
.
91
)
(4
9
.
68
)
05
5
.
76
)
(1
8
0
.
92
)
62
.
(4
9
.
59
)
(5
.
35
)
22
8
.
65
)
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
St
.

J
o
s
e
p
h
91
5
.
83
0
.
4
6
)
14
7
.
23
2
.
96
0
.
13
)
13
8
.
53
,
4
1
0
.
87
9
.
4
6
)
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fi
r
m

C
u
s
t
o
m
e
r
s
(2
,
4
4
8
44
6
.
84
)
(1
9
0
04
0
.
38
)
(1
4
39
3
.
74
)
37
6
.
66
)
65
9
25
7
.
62
)
26
9
.
(1
4
38
6
.
96
)
64
3
.
28
)
66
2
01
8
.
74
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
06
4
22
2
.
(6
2
6
60
9
.
05
)
19
,
37
7
.
7,
4
5
6
99
1
.
(4
5
9
,
4
0
1
.
63
)
06
8
.
2
2
01
5
65
7
.
(5
5
7
16
0
.
73
)
73
6
80
2
.
(6
4
2
66
1
.
37
)
(1
9
1
,
4
6
4
.
4
6
)
(1
4
50
1
.
60
)
28
1
.
90
1
,
4
5
6
.
(4
6
7
34
7
.
25
)
18
,
4
1
4
.
(1
4
50
1
.
60
)
67
4
.
4,
4
4
9
69
6
.
(5
7
2
03
0
.
07
)
Pa
g
e

3
0
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

19
1
.
4
1
/
1
9
1
0
1
0
F :
l
c
r
a
i
g
l
i
d
a
h
o
I
0
6
T
r
a
c
k
l
(
R
e
c
a
p
1
9
1

01

xl
s
l
6/
3
0
1
0
6
7/
3
1
/
0
6
7/
3
1
/
0
6
8/
3
1
/
0
6
8/
3
1
/
0
6
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
6/
3
0
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
7/
3
1
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
CD
A

R
e
s
o
r
t
34
3
.
2
8
(7
2
.
7
7
)
17
.
02
6
.
83
2
.
97
)
46
8
.
(7
7
.
1
3
)
(4
1
2
.
38
)
16
9
.
24
)
51
3
.
(8
3
.
12
)
(5
.
70
)
CD
A

F
i
b
e
r

F
u
e
l
86
.
87
.
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d
p
o
i
n
t
85
.
14
5
.
(3
,
4
6
8
.
32
)
81
.
75
7
.
39
3
.
11
)
75
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
(5
.
57
)
23
4
.
22
)
(5
.
59
)
23
9
.
81
)
(7
5
.
65
)
28
2
.
(4
5
.
76
)
(5
.
4
0
)
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
St
.

J
o
s
e
p
h
12
4
.
65
6
.
4
6
50
6
.
74
)
11
1
.
26
0
.
25
8
.
70
)
10
1
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fi
r
m

C
u
s
t
o
m
e
r
s
06
5
.
2
1
(1
4
42
8
.
83
)
58
7
.
99
)
61
4
97
0
.
35
)
55
8
.
(1
4
,
4
2
4
.
4
7
)
(6
,
4
4
6
.
00
)
54
8
28
1
.
95
)
81
6
.
(1
4
37
2
.
7
2
)
27
7
.
6
4
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
16
,
84
2
.
6,
4
7
5
33
9
.
(3
4
4
25
0
.
71
)
75
8
.
14
6
84
6
.
(2
3
5
,
37
7
.
21
)
07
2
.
68
,
4
0
8
.
4
9
(1
4
50
1
.
60
)
10
,
4
7
6
.
94
2
04
9
.
(3
5
6
05
8
.
74
)
02
7
.
(1
4
50
1
.
60
)
50
1
.
66
9
01
8
.
(2
4
4
27
3
.
91
)
61
3
.
(1
4
50
1
.
60
)
96
1
.
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
.
4
1
/
1
9
1
0
1
0
F:
\
c
r
a
i
g
\
i
d
a
h
o
\
0
6
T
r
a
c
k
\
(
R
e
c
a
p
1
9
1

0
1

O
.
xl
s
l
ES
T
.
ES
T
.
ES
T
.
ES
T
.
9/
3
0
/
0
6
9/
3
0
/
0
6
ES
T
.
ES
T
.
10
/
3
1
/
0
6
10
/
3
1
/
0
6
ES
T
.
ES
T
.
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
Co
m
m
o
d
i
t
y
De
m
a
n
d

&
Ca
s
c
a
d
e
In
t
e
r
e
s
t
Ba
l
a
n
c
e
8/
3
1
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
9/
3
0
/
0
6
De
f
e
r
r
a
l
Ca
p
a
c
i
t
y

R
e
I
.
Re
v
e
n
u
e
10
/
3
1
/
0
6
De
f
e
r
r
a
l
s
De
f
e
r
r
a
l
s
CD
A

R
e
s
o
r
t
15
6
.
79
)
68
6
.
49
9
.
(5
8
.
4
9
)
(8
.
98
)
(3
,
03
7
.
68
)
14
5
.
56
)
(3
1
4
.
97
)
(5
8
.
4
9
)
(1
0
.
74
)
56
7
.
4
4
)
CD
A

F
i
b
e
r

F
u
e
l
87
.
87
.
87
.
Id
a
h
o

A
s
p
h
a
l
t
IM
S
In
t
e
r
s
t
a
t
e

A
s
p
h
a
l
t

-

S
a
n
d

p
o
i
n
t

43
9
.
26
9
.
73
.
78
3
.
(7
8
6
.
70
)
73
.
4
8
07
0
.
Ko
o
t
e
n
a
i

M
e
d
i
c
a
l

C
e
n
t
e
r
Li
g
n
e
t
i
c
s
Me
r
r
i
t
t

B
r
o
t
h
e
r
s
Po
t
l
a
t
c
h
St
i
m
s
o
n

L
u
m
b
e
r

(
R
i
v
e
r

A
v
e
)
08
3
.
84
)
(5
.
21
)
08
9
.
05
)
(5
.
22
)
09
4
.
27
)
St
i
m
s
o
n

L
u
m
b
e
r

(
S
e
l
t
i
c
e
)
St
.

J
o
s
e
p
h
39
,
10
3
.
71
1
.
98
.
39
,
91
3
.
29
7
.
25
)
96
.
71
3
.
Un
i
v
e
r
s
i
t
y

o
f

I
d
a
h
o
Fi
r
m

C
u
s
t
o
m
e
r
s
48
0
,
11
5
.
4
2
)
12
3
41
9
.
(1
4
,
4
4
3
.
11
)
06
4
.
06
)
37
7
20
3
.
39
)
(7
7
77
8
.
03
)
(1
4
,
4
4
3
.
11
)
05
8
.
27
)
(2
,
4
7
5
48
2
.
80
)
Sa
l
e
s

C
u
s
t
o
m
e
r
s
92
6
,
54
2
.
60
8
.
91
3
.
01
9
,
06
4
.
(4
0
2
97
9
.
4
9
)
54
3
.
63
0
62
8
.
50
8
81
7
.
27
6
.
12
3
91
9
.
(1
4
50
1
.
60
)
00
7
.
70
6
51
8
.
(4
0
8
20
9
.
00
)
(7
8
09
3
.
00
)
(1
4
50
1
.
60
)
64
0
.
21
4
35
5
.
Pa
g
e

3
2
Wa
s
h
i
n
g
t
o
n

W
a
t
e
r

P
o
w
e
r

C
o
m
p
a
n
y
St
a
t
e

o
f

I
d
a
h
o
An
a
l
y
s
i
s

o
f

A
c
c
o
u
n
t

1
9
1
0
1
0
'
To
t
a
l
Co
m
m
o
d
i
t
y
De
m
a
n
d
Ca
s
c
a
d
e
In
t
e
r
e
s
t
A&
G
Be
n
c
h
m
a
r
k
Of
f
-
Sy
s
t
e
m
Ac
c
t

1
9
1
0
1
0
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Re
v
e
n
u
e
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Sa
l
e
s
/
C
a
p

R
e
i
6/
3
0
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
30
3
39
5
.
4,
4
1
0
33
3
.
37
3
13
1
.
(1
9
2
17
1
.
98
)
30
,
15
4
.
(2
6
,
4
7
5
.
03
)
57
2
56
6
.
55
)
(7
1
9
01
0
.
65
)
7/
3
1
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
20
5
,
4
1
5
.
68
0
.
34
0
,
29
1
.
(1
4
65
9
.
4
0
)
(1
5
3
89
7
.
4
8
)
In
t
e
r
e
s
t
00
2
.
00
2
.
7/
3
1
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
51
2
81
3
.
4
6
44
4
01
3
.
71
3
,
4
2
3
.
(2
0
6
83
1
.
38
)
15
7
.
(2
6
,
4
7
5
.
03
)
57
2
56
6
.
55
)
(8
7
2
90
8
.
13
)
8/
3
1
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
46
6
,
4
9
2
.
32
4
16
3
.
32
7
37
7
.
(1
4
65
9
.
4
0
)
(1
7
0
,
38
8
.
76
)
In
t
e
r
e
s
t
57
1
.
57
1
.
8/
3
1
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
98
3
,
87
8
.
76
8
17
7
.
04
0
80
0
.
(2
2
1
,
4
9
0
.
78
)
38
,
72
9
.
(2
6
47
5
.
03
)
57
2
56
6
.
55
)
04
3
,
29
6
.
89
)
9/
3
0
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
16
5
,
64
1
.
10
9
,
4
0
2
.
89
8
.
(1
4
65
9
.
4
0
)
In
t
e
r
e
s
t
94
3
.
94
3
.
9/
3
0
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
15
5
,
4
6
3
.
87
7
57
9
.
11
1
69
8
.
(2
3
6
15
0
.
18
)
67
3
.
(2
6
,
4
7
5
.
03
)
57
2
56
6
.
55
)
04
3
29
6
.
89
)
10
/
3
1
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
11
4
73
5
.
18
8
54
2
.
(5
9
,
14
7
.
60
)
(1
4
65
9
.
4
0
)
In
t
e
r
e
s
t
85
4
.
85
4
.
10
/
3
1
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
27
8
05
3
.
06
6
12
2
.
05
2
55
1
.
(2
5
0
80
9
.
58
)
52
7
.
(2
6
,
4
7
5
.
03
)
57
2
56
6
.
55
)
04
3
29
6
.
89
)
11
/
3
0
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
21
2
02
0
.
63
5
65
0
.
(4
0
8
,
97
0
.
66
)
(1
4
65
9
.
4
0
)
Tr
a
c
k
e
r

T
r
a
n
s
f
e
r
30
3
39
5
.
35
)
(4
,
4
1
0
,
33
3
.
05
)
(3
7
3
13
1
.
53
)
19
2
17
1
.
(3
0
,
15
4
.
98
)
26
,
4
7
5
.
57
2
,
56
6
.
71
9
,
01
0
.
In
t
e
r
e
s
t
80
1
.
80
1
.
11
/
3
0
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
19
3
,
4
8
0
.
4
0
29
1
44
0
.
27
0
,
4
4
8
.
(7
3
29
7
.
00
)
29
,
17
4
.
(3
2
4
28
6
.
24
)
12
/
3
1
/
0
5
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
80
4
74
2
.
62
7
06
4
.
(8
0
7
,
66
2
.
53
)
(1
4
65
9
.
4
0
)
No
t
e

1
In
t
e
r
e
s
t
43
1
.
9,
4
3
1
.
12
/
3
1
/
0
5
En
d
i
n
g

B
a
l
a
n
c
e
00
7
65
4
.
4
9
91
8
,
50
5
.
(5
3
7
,
21
3
.
55
)
(8
7
95
6
.
4
0
)
38
,
60
5
.
(3
2
4
28
6
.
24
)
1/
3
1
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
99
7
53
3
.
4
8
55
4
76
3
.
(5
4
2
,
57
0
.
12
)
(1
4
65
9
.
4
0
)
No
t
e

1
In
t
e
r
e
s
t
26
6
.
26
6
.
1/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
02
1
45
4
.
8,
4
7
3
26
8
.
07
9
78
3
.
67
)
(1
0
2
61
5
.
80
)
87
1
.
(3
2
4
28
6
.
24
)
2/
2
8
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(6
6
3
,
05
3
.
65
)
(1
5
2
,
99
1
.
18
)
(4
9
5
,
4
0
3
.
07
)
(1
4
65
9
.
4
0
)
No
t
e

1
In
t
e
r
e
s
t
72
4
.
72
4
.
2/
2
8
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
37
5
12
5
.
32
0
,
27
6
.
57
5
,
18
6
.
74
)
(1
1
7
27
5
.
20
)
59
6
.
4
3
(3
2
4
28
6
.
24
)
Pa
g
e

3
3
Wa
s
h
i
n
g
t
o
n

W
a
t
e
r

P
o
w
e
r

C
o
m
p
a
n
y
St
a
t
e

o
f

I
d
a
h
o
An
a
l
y
s
i
s

o
f

A
c
c
o
u
n
t

1
9
1
0
1
0
To
t
a
l
Co
m
m
o
d
i
t
y
De
m
a
n
d
Ca
s
c
a
d
e
In
t
e
r
e
s
t
A&
G
Be
n
c
h
m
a
r
k
Of
f
-
Sy
s
t
e
m
Ac
c
t

1
9
1
0
1
0
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Re
v
e
n
u
e
De
f
e
r
r
a
l
De
f
e
r
r
a
l
Sa
l
e
s
/
C
a
p

R
e
i
3/
3
1
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(6
5
3
44
3
.
68
)
(2
2
1
68
4
.
74
)
(4
1
7
09
9
.
54
)
(1
4
65
9
.
4
0
)
No
t
e

1
In
t
e
r
e
s
t
12
1
.
12
1
.
3/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
73
6
,
80
2
.
09
8
59
2
.
99
2
28
6
.
28
)
(1
3
1
93
4
.
60
)
86
,
71
7
.
4
4
(3
2
4
28
6
.
24
)
4/
3
0
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(8
4
8
62
7
.
4
3
)
(6
4
2
66
1
.
37
)
(1
9
1
,
4
6
4
.
4
6
)
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
13
,
28
1
.
28
1
.
4/
3
0
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
90
1
45
6
.
45
5
93
0
.
18
3
75
0
.
74
)
(1
4
6
,
4
3
6
.
20
)
99
8
.
(3
2
4
28
6
.
24
)
5/
3
1
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(4
6
3
,
4
3
4
.
16
)
(4
6
7
,
34
7
.
25
)
18
,
4
1
4
.
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
67
4
.
67
4
.
5/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
44
9
,
69
6
.
98
8
58
3
.
16
5
33
6
.
05
)
(1
6
0
93
7
.
80
)
11
1
67
3
.
(3
2
4
28
6
.
24
)
6/
3
0
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(5
1
8
12
3
.
18
)
(5
7
2
03
0
.
07
)
68
,
4
0
8
.
4
9
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
10
,
4
7
6
.
10
,
4
7
6
.
6/
3
0
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
94
2
04
9
.
6,
4
1
6
55
3
.
09
6
,
92
7
.
56
)
(1
7
5
,
4
3
9
.
4
0
)
12
2
14
9
.
(3
2
4
28
6
.
24
)
7/
3
1
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(2
8
2
53
3
.
25
)
(3
5
6
,
05
8
.
74
)
88
,
02
7
.
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
50
1
.
50
1
.
7/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
66
9
,
01
8
.
06
0
,
4
9
4
.
00
8
90
0
.
4
7
)
(1
8
9
,
94
1
.
00
)
13
1
65
1
.
(3
2
4
28
6
.
24
)
8/
3
1
/
0
6
Ac
t
u
a
l

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(1
6
9
16
2
.
19
)
(2
4
4
27
3
.
91
)
89
,
61
3
.
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
96
1
.
96
1
.
8/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
50
8
81
7
.
81
6
,
22
0
.
(1
,
91
9
28
7
.
15
)
(2
0
4
44
2
.
60
)
14
0
61
2
.
(3
2
4
28
6
.
24
)
9/
3
0
/
0
6
Es
t
i
m
a
t
e
d

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
18
8
,
69
3
.
4
0
27
6
.
12
3
91
9
.
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
00
7
.
00
7
.
9/
3
0
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
70
6
51
8
.
89
5
,
4
9
6
.
79
5
36
8
.
15
)
(2
1
8
,
94
4
.
20
)
14
9
62
0
.
(3
2
4
28
6
.
24
)
10
/
3
1
/
0
6
Es
t
i
m
a
t
e
d

C
u
r
r
e
n
t

D
e
f
e
r
r
a
l
s
(5
0
0
80
3
.
60
)
(4
0
8
,
20
9
.
00
)
(7
8
09
3
.
00
)
(1
4
50
1
.
60
)
No
t
e

1
In
t
e
r
e
s
t
64
0
.
64
0
.
10
/
3
1
/
0
6
En
d
i
n
g

B
a
l
a
n
c
e
21
4
35
5
.
48
7
28
7
.
87
3
,
4
6
1
.
15
)
(2
3
3
,
4
4
5
.
80
)
15
8
26
0
.
(3
2
4
,
28
6
.
24
)
NO
T
E

1

-

C
a
p
a
c
i
t
y

R
e
l
e
a
s
e
s

h
a
v
e

b
e
e
n

n
e
t
t
e
d

a
g
a
i
n
s
t

t
h
e

D
e
m
a
n
d

D
e
f
e
r
r
a
l
Pa
g
e

3
4
A VIST A UTILITIES
Exhibit "
Pipeline Tariff Sheets
Used In This Filing
September 28, 2006
Northwest Pipeline Corporation
FERC Ga1!l Tariff
Third Rev~ed Vohlme No.
Thlrty-t"lrst Revised Sheet No.
Supersedin2
Thirtieth Revised Sheet N o. ~
STATEMENT OF RATES
Effective Rates Applicable to Rate Schedules TF-l, TF-2 and TI-l
(Dollars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate
Minimum Maximum
Currently
Effective
Tariff Rate (3
Minimum MaximumACA(2)
Rate Schedule TF-l (4) (5)
Reservation
(Large Customer)
System-Wide 00000 43712 00000 . 4371-?
15 Year Evergreen Exp.00000 41621 . 00000 41621
25 Year EVergreen Exp.00000 3974B 00000 39748
Volumetric
(Large CUstomer)
System-Wide 00756 00756 0'olBO 00936 00936
15 Year Evergreen Exp.00369 00369 00180 00549 00549
25 Year Evergr~en Rxp.00369 00369 00180 00549 00549
(Small Customer)(6)00756 88180 00180 00936 . B8360
Scheduled Overrun 00756 44468 00180 00936 44648
Rate Schedule TF-2 (4) (5)
Reservation 00000 43712 00000 43712
Volumetric 00756 00756 00756 00756
scheduled Daily Overrun 00756 44468 00756 44468
Annual Overrun 00756 4446B 00756 44468
Ra te Schedule TI-
Volumetric (7)
scheduled Overrun
00756'
00756
44468
44468
00180
00180
00936
00936
44648
44648
TUUM by: Laren M.Gertsc~ Director
Issued on: Jun~ 30, 2006 Effective: Au~rt 1; 2006
Northwest Pipeline Corporation
FERC Gas Tariff
Third Revised Volume No.
Seventeenth Revilled Sheet No.
Sapersedlne
Sirleenth Reviled She.et No.
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedule LS-l
(Dollars per Dth)
Type of Rate
CUrrently EffectiveTariff Rate (1)
Demand Charge (2 )
Capacity Charge (2)
03154
00403
Liquefaction
vaporization
64110
04184
iFootnotes
(1 )Shippers receiving service under this rate schedule are required to
furnish fuel reimbursement in-kind at the rate specifie~ on Sheet No.
14.
(2)Rates are daily rates computed on the basis of 365 days per' year, exc~pt
that rates for leap re~rs are computed on the basis of 366 days.
bsl,lOO by: Laren M.Germ:h, Director
Issued on: June 30. 2006 Effective: Au~rt 1. 2006
NOVA Gas Transmission Ltd.Table of Rates, Tolls and Charges
TABLE OF RATES, TOLLS & CHARGES
Service Rates, Tolls and Charges
Rate Schedule FT-Refer to Attachment "1" for applicable FT-R Demand Rate per month & Surcharge for
each Receipt Point
Average Firm Service Receipt Price (AFSRP)$141.4211 0
Rate Schedule FT-Refer to Attachment "I" for applicable FT-RN Demand Rate per month & Surcharge
for each Receipt Point
- "'
0 -
'- -' ';---""
Rate Schedule FT-FT -D Demand Rate per month (Apr - Oct). $141.4211 03 3 .
FT-D Demand Rate per month (effective November I, 2006)'f74iCrr;
~ .
Rate Schedule STFT STFT Bid Price.Minimum bid of 100% of FT -D Demand Rate
Rate Schedule FT-FT-DW Bid Price.Minimum bid of 125% ofFT-D Demand Rate
Rate Schedule FT-FT-A Commodity Rate 0.48/10
Rate Schedule FT-Refer to Attachment "2" for applicable FT-P Demand Rate per month
Rate Schedule LRS Contract Term Effective LRS Rate ($/J O'Iday)
5 years
10 years
15 years
20 years 6.45
Rate Schedule LRS-LRS-2 Rate per month $50 000
10. Rate Schedule LRS-LRS-3 Demand Rate per month (Jan - April)$196.3211 Oj
LRS-3 Demand Rate per month (effective May 1 2006)$129.55/J0
11. Rate Schedule IT-Refer to Attachment "1" for applicable IT-R Rate & Surcharge for each Receipt Point
12. Rate Schedule IT-IT-D Rate (Apr - Oct)1211 Oj
IT-D Rate (effective November 1,2006)1354/GJ
) 3. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment "I" to the applicable
Schedule of Service
14. Rate Schedule PT Schedule No PT Rate PT Gas Rate
9005-01000-$ 164.91/d 0 103 3 Id
9006-0 I 000-15.05/d 1.0 103 3 Id
15. Rate Schedule OS Schedule No.Charge
2003004522-83.333.1 month
2003034359-899.1 month
2004168619-437.1 month
2006222805-1 month
2006222973-856.1 month
2006222974-66.1 month
2006223044-171.00 1 month
2006223045-576.1 month
2006223046-294.1 month
2006223047-68.1 month
2006224148-92.1 month
2006224149-536.1 month
2006224337-66,1 month
2006224475-111.00 1 month
2006224607-588.1 month
16. Rate Schedule CO2 Tier CO2 Rate ($/1 Oj
674.
532.41
390.43
TARIFF Effective Date: April 1 , 2006 as per EUB Order U21 006-
(Amended April 6, 2006)
TransCanada B.C. System Gas Transportation Service Documents TAB 3 , Page 2
RATES STATEMENT AND CALCULATION METHODOLOGY
Statement of Effective Rates and Charges
Effective Rates
FS-l Firm Service
Demand Rate (cents/GJlKm/Month*
' '----:::'~
l..
.~.
~5~.
~~_~~~_
IS-l Interruptible Service
Commodity Rate (cents/GJ/Km*0450404091
* Total distance of pipeline is 170.7 Ian
Company Use Gas
Shipper s Share of Company Use Gas shall be detennined pursuant to Section 10.5 of the
General Tenns and Conditions.
Effective Date: January 1 , 2006
REVISED INTERIM
Page 8.4
Westcoast Energy Inc.
TOll SCHEDULES - SERVICE
APPENDIX A
DEMAND AND COMMODITY TOllS
TRANSPORTATION SERVICE - SOUTHERN
Firm Transportation Service - Southern
Terasen
PNG Inland Huntingdon Kingsvale to
Service Term Delivery Point Delivery Area Delivery Area Huntin don
1 year 109.264.484.40 219.
2 years 106.256.470.213.43
3 years 103.249.456.207.
4 years 102.246.451.48 204.
"..
5 years or more 1 0 1.244.146.202.76
Demand Tolls
$/10 /mo.
" For Firm Transportation Service - Southern provided by Westcoast pursuant to a Firm Service Agreement
dated April 15 2002 between Westcoast and Terasen Gas Inc.
Plus the amount of tax on fuel gas consumed in operations payable by Westcoast under the Motor
Fuel Tax Act (British Columbia) allocated to Shipper for each day in the month.
ADS and Interruptible Transportation Service - Southern
Commodity Tolls$/1 0
PNG Inland Huntingdon
Months Delivery Point Delivery Area Delive Area
November 811 11.597 21.234
to March
April to 608 698 15.925
October
Plus the amount of tax on fuel gas consumed in operations payable by Westcoast under the Motor
Fuel Tax Act (British Columbia) allocated to Shipper for each day in the month.
Import Backhauf Service
Commodity Tolls
$/1 0
Inland PNG Compressor
Delive Area Delivery Point Station No.
637 16.423 21.234
227 12.317 15.925
Months
November
to March
April to
October
Plus the amount of tax on fuel gas consumed in operations payable by Westcoast under the Motor
Fuel Tax Act (British Columbia) allocated to Shipper for each day in the month.
Effective Date: July 10, 2006