20110826Stipulation-Settlement.pdf

AfT ACHMENT 1
David J. Meyer, Esq.
Vice President and Chief Counsel of
Regulatory and Governmental Af'fairs
A vist Corporation
1411 E. Mission Avenue
P.O. Box 3727
Spokane, Washington 99220
Phone: (509) 495~4316, Fa1(: [phone]
Donald L. Howel!, II
Kristine Sasser
Deputy Attorneys General
Idaho Public Utilties Commission Sta
P.O. Box 83720
Boise,ID 83720-0074
Phone: [phone], Fax: [phone]
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF AVISTA CORPORATION DBA )
A VISTA UTILITIES FOR AUTHORITY TO )
INCREASE ITS RATES AND CHARGES )
FOR ELECTRIC AND NATURA GAS )SERVICE IN IDAHO )
CASE NOS. AVLJ-E-ll-01
AVU-G-lI-01
STIPULATION AND SETTLEMENT
This Stipulation is entered into by and among A vista Corporation, doing business as
Avista Utilties ("A vista" or "Company"), the Staff of the Idaho Public Utilties Commission
("Staff), Clean vater Paper Corporation ("Clearwater"), Idaho Forest Group, 1.LC ("Idaho
Forest"), the Community ActionPartcrship Association of Idaho ("CAP Al"), and the Idaho
Conservation League ("Conservation League"). These entities are collectively referred to a') the
"Parties, II and represent all paries in the above-referenced cases that paricipated in settlement
discussions. The Paries understand this Stipulation is subject to approval by the Idaho Public
Utilties Commission ("¡PUC" or the "Commission").
STIPULATION AND SETfLEMENT-AVU-E/G-I1-01 Page 1
I. INTRODUCTION
1. The terms and conditions of this Stipulation are set fbrth herein. The Paries agree
tht this Stipulation represents a fair, just and reasonable compromise of all the issues raised in
the proceeding and that this Stipulation and its acceptance by the Commission represent a
rea~onable resolution of the multiple issues identified in this Stipulation. The Parties, therefore,
recommend that the Commission, in accordance 'With RP 274, approve the Stipulation and all of
its terms and conditions without material change or condition.
n. BACKGROUND
2. On July 5, 2011, Avista fied an Application with the Commission for authority to
increase revenue from electic and natural gas service in Idaho by 3.7% and 2.7%, respectively.
If approved, the Company's revenues for electric base retail rates would have increased by $9.0
millon annually; Compan)' revenues for natural gas service would have increased by $1.9
million annualy. The Company requested an efIective date of August 5, 2011 for its proposed
electnc and natural gas rate increases. By Order No. 32292, dated July 14.2011, the Commission
susnded the proposed schedules of mtes and charges for electric and natural gas service for a
period of thirty (30) days plus five (5) months, from August 5, 201 1, until such time as the
Commission enters an Order accepting, rejecting or modifying the Application in this matter.
3. Petitions to intervene in this proceeding were filed by Clearwater, Idaho Forest,
CAPAI and the Idaho Conservation League. By various orders, the Commission gmnted these
interventions. ,S'ee, IPUC Order Nös. 32296 and 323 i 7.
4. A settlement cönference was noticed and held in the Commission oflces on
August 17, 20 1 i. and was attended by signatories to this Stipulation; further discussions ensued.
STIPULATION AND SETTLEMENT - AVU-E/G-II-01 Page 2
Based upon the settlement discussions among the Parties, as a compromise of positions in this
case, and for other consideration as set fort below, the Parties agree to the following terms:
III. TERMS OF THE STIPULATION AND SETTLEMENT
5. Overview of Settement and Revenue Requirement. The Pares agree that Avista
should be allowed to implement revised tarff schedules designed to recover $2.8 minion in
additional annual electric revenue, and $1.1 mí1ion in additional annual natural gas revenue,
which represent a 1.1 % and 1.6% increase in electrc and natural ga..: annual base tariff revenues,
respectively. New electric and natural gas rates would become eiJective October 1.2011.
The Parties agree that this Settlement is not contingent upon any specific methodology
for individual components of the revenue requirement detemlÌnation, but all Paries support the
overal increase to the Company's revenue requirement, and agree that the overall increase
represents a fair, just and reasonable compromise of the issues in this proceeding and that this
Stipulation is in the public interest.
6. Net Impact of All Proposed Revenue Adjustments on October 1,2011. By means
of separate filings, several other rate adjustments arc proposed to also take effect on October 1,
201 L With respect to electric service, these proposed adjustments include the following!: a
decrca'i of $2.2 milion in Schedule 59 for Residential Exchange benefits for residential and
small farm customers; a decrease of $15.5 milion in Schedule 66 Power Cost Adjustment (peA)
rates. In addition, an increase of $8.7 milion for the previously-approved adjustmentt'or
Deferred State Income taxes (DSIT) in Schedule 99, as part of the Settlement approved in Ca,;e
No.(s) AVU-E-IO-Ol and AVU-G-IO-Ol wil take effect on October 1, 20ll. After taking into
account the agreed-upon increas of $2.8 millon in electric general rate increase revenues, the
net overall reduction resulting from all of the proposed aforementioned adjustments, if approved
i These proposed rate changes ar included for ilustrative purposes and ar not par of this Stipulation.
STIPLJLArION AND SETTLEMENT-AVtJ-E/G-l1-01 Page 3
as fied would total approximately $6.2 millon? Attachment A sets forth these proposed
October 1 adjustments in more detail, and by service schedule. The following table summarzes
these proposed revenue adjustments:
Electri - Oeober li2ll1 1 Revenue Change
Schedul 99 - DSIT Increas
Schedul 59 - Residentl Exchae
Schedul 66 - PCA Decrease
GRC Rate Increase
Total Revenue Chaßge
$ 8,698,844
$ (2,207,088)
$ (15,517,483)
$ 2,800,000
$ (6,225,727)
With respc.'Ct to natural gas service, the following rate adjustments. by means of separate
filings, ar proposed to tae effect on October 1,2011.1: an increase of$O.8 milion in Schedules
150/155 for Purchased Gas Costs (POAt; a decrease of $2.9 milion in Demand-Side
Management (DSM) witT rider Schedule 191. In addition, an increase of $0.5 milion for the
previously-approved adjustment for Deferred State Income Taxes (DSIT) in Schedule 199, as
par of the Settlement approved in Case No.(s) AVtJ-E- i 0-0 i and A VtJ-G- I 0-0 1 wil take effect
on October 1, 2011. After taking into account the agreed-upon increase of $1.1 milion in
natural gas general rate revenues, the net overall decrease resulting from an of the proposed
aforementioned adjustments., if approved as filed, would be $0.525 millon. Attachment A sets
forth these proposed October 1, 2011 adjustments in more detail, and by service schedule. The
following table summarizes these proposed revenue adjustments:
i As pa of this Settlement. Avista has also agreed to withdraw its fied-for decrease of $0.74 milion in electric
Demand.Side Management (DSM) TariffScheduJe 91, and wHl do so by means ofa separate filng.
J Thes proposed rate changes are included for ilustative purposes and are not par ofthis Stipulation.4 On August 26, 20ì l, Avista wil update its pending PGA (Case No. A VU-G-l 1 -04) to reflect a decline in forward
natural gas prices since the August 15,2011 PGA filing which, if approved by the Commission, would result in a
0.98% overall increase versus the previously-tiled 1.53% increase, The revised proposed rates have been
incorporaied into the net proposed October i. 20J i Revenue Change and Attahments A and C to this Stipulation.
STIPULATION Ai'fD SETTLEMENT - AVU-E/G.11-oi Page 4
Natul Gas - October i, 2011 Revenue Cbange
Schedule 199 - DSlT Increase $
Schedui 150/155 - PGA Increase $
Schedul 19 i - DSM Decrease $
GRC Rate Increase $Total Revenue Cbange $
470,423
776.190
(2,871,236)
1,100.000
(524,623)
7. Effective Date for New Rates In This Proceeding. The Parties agree, as an
integral par of the Settlement, that the effective date fur new electrc and natural gas rates should
be October 1, 2011.
8. Limitation on Effective Date of Any New Rates Established By Subsegu~nt
General Rate Filng. The Company agrees that it \\rill not seek to make effective a change in
bas electric or natural gas rates prior to April 1, 2013, by means ofa general rate filng. (Any
filing of a general rate case, however, may be made prior to April 1, 2013, but shall not request
an effective date prior to April 1, 2013.) This wil not prevent the Company, however, from
otherwise seeking to implement other rate changes aftècting the rates biled to customers,
including, but not limited to, adjustments under the power cost adjustment (PC A) mechaism,
purchased gas cost adjustments (PGA); DSM tarff rider a4iustments; etc.
9. PCA Authorized Level of Expense. The new level of power supply expense, retail
load and Clearwater Paper generation, and Load Change Adjustment Rate resulting from the
settlement revenue requirement for puroses of the monthly peA mechanism calculations, ar
detailed in Attachment B.
10. Cost of Service. As par of this rate case, the Company prepared an analysis of
using a peak credit method of classifying production costs, allocating 100% of transmission costs
to demand, and allocating transmission costs to reflect any peak and oft:'peak sea')onal cost
diftèrences on a weighted twelve month ba')is. The Parties have agreed to exchange information
and convene a public workshop, prior to the Company's next general rate case, with respect to
STIPULATION AND SETTLEMENT - AVU-E/G-II-01 PageS
the method of allocation of demand and energy among the customer classes such as the possible
use of a revised peak credit method for classifying production costs, as well as consideration of
the use of a 12 Coincident Peak (CP) (whether "weighted" or not) versus a 7 CP or other method
for allocating tranmission costs. This workshop wil also address the merits of inclining or
declining block rates for service schedules 11, 2 i, 25 and 31. The Paries agreed, however, to
spread the electric rate increase on a uniform percentage basis for puroses of this Setlement.
As for natural gas, the Company prepared a cost of service study and proposed that all
rate schedules he moved to unity. For settlement purposes, the Parties agreed to spread the
natural gas rate increase on a uniform percentage ha-sis.
11. Rate Spreagl,Rate Design.
(a) As indicated above, the Parties agree that the increase in base revenue would
be spread to all electric and natual gas rate schedules on a uniform percentage basis.
(b) The Parties agree that there wil be an increase in the basic charges, monthly
minimum charges, and demand charges in Schedules 11, 21, 25 and 146, as shown in
Attachment
(c) A uniform percentage increase wil be applied to each energy rate within each
electric service schedule excluding Schedule 1, residential service, \vhere the block
differential remains constat. In addition. the second block in Schedule 11 wil be
reduced by $0.00773 as contemplated in the Company's original fiingS. and the
remaining revenue requirement, after accounting for the changes in the basic charge and
demand charge. wil be applied to the first energy block.
S See Direct Testimony of Patrick Ehrbar, Page 15.
STIPULATION AND SETTLEMENT - A VlJ-E/G-Il-O 1 Page 6
(d) The Parties agree that the current residential electric basic charge of $5.00 per
month wíl be increased to $5.25, and the residential natural gas basic charge of $4.00 per
month will be increased to $4.25.
(e) Attachment C provides a summar of the curent and revised rat~sand
charges (as per the Settlement) for electric and natural gas service.
12. Resulting Percentage Increase bv Schedule. The following tables reflect the
agreed-upon pt"'centage increase by schedule for electrc and natural gas service:
FJectrc Increase Percentqe by Schedule
Increase ¡nBase Net Increase in
Rate Schedul Rates Billing Rates *
ResidentIìl Schedul 1 1.1%-2.1%
Genera Serve Schedul 11/12 1.%-1.1%
Large Gem."lal Service Schedul 21/22 1.1%-1.4%
Ex Large General Serve Schedul 25 1.%-3.9%
Clearwater Paper Schedul 25P U%-5.2%
Pumin Service Scheul 31/32 1.1%0.0%
Stret & Area Ligts Scheduls l.%2.7%
Overan 1.1 CV,~2.4°/o
* Net Increas inlues th effcts ofthe proposed chaes in Schedul 59 (Residentia
Exchang), Schedul 66 (Power Cost Adjustment), Scheul 99 (Dererrd State Income
Tax) and th General Rate Increas, al effctiv on October I, 20 II if approved.
N t IG I p bySbdulaurasncreaseercentagecee
Increase in Base Net Increase in
Rate Schedule Rates Billing Rates**
General Sere Schedul 101 1.6%-0.5%
Large General Service Scheul 11líl12 1.6%.1.8%
Interrtible Sales Serve Schedul 131/132 1.6%-10.6%
Transporttin Service Scheul 146 1.6%3.0%
Overall 1.6%-0.8%
** Net Increase inlues the effcts of th proposed changs in Schedul 150/155
(PGA), Schedul 19 ¡ (Energy Effiency Rier), Schedul 199 (Detèrred State Income
Tax) an th General Rate Increase, an efictIV on October 1, 201 i if approved.
STIPULATION AND SETTLEMENT -' AVU-E/G-l 1-01 Page 7
13. Customer Service-Related Issues.
(a) Funding for Outreach for Low-Income Conservation. The Parties agree to
annual funding of $50,000 to CAP AI for purposes of providing low-income outreach and
education concerning conservation (representing an increase of $ i 0,000 from previous
funding levels). This amount will be funded through the Energy Efficiency Tariff Rider
(Schedules 91 and 191), and win be in addition to the $700,000 of Low.lncome
\VeatherizatIon funding currently in place.
(b) Collaboration on Low-Income Weatherization. The Company and interested
paries win meet and confer prior to the Company's next general rate tilng in order to
assess the Low Income Weatherization and Low Income Energy Conservation Education
Programs and discuss appropriate levels of low.income weatheri7.ation fuding in the
future.
14. Other Accounting Matters/Deferrals. The Paries agree to the following
accounting treatment for the following items:
(a) Costs Associated With Acquisition From Palouse Wind. LLC. The Company
has signed a 30-year power purchase agreement with Palouse Wind, LLC, to acquire all
of the power produced by a wind project that is expected to produce approximately 40
aMW. Deliveries are expected to begin in the second half of 2012. The annual cost of
the Idaho share of the purchased power under the contract is expected to be
approximately $6.5 milion. Under terms of this Settlement, the Company shall include
100% of the costs associated with power purchases from the wind project through the
Power Cost Adjustment (PCA) until such costs, subject to prudence review, are reflected
in genera rates.
STIPULATION AND SETTLEMENT - A VU.EíG-l1-0 1 Page 8
(b) Deferred Accounting Treatment For The Variability In Certin Generating
Plant Operation and Maintenance (O&M) Costs. In order to address the large variability
in year-to~year O&M costs, beginning in 2011 the Company wil be allowed to defer
changes in O&M costs related to its Coyote Springs 2 (CS2) natura gas-fired generating
plant located near Boardma, Oregon, and its fifteen (15) percent ownership share of the
Colstrip 3 & 4 coal-fired generating plants located in southeastern Montaa.
The Company win compare actua, non-fuel, O&M expenses for the Coyote
Springs 2 and Colstrip 3 & 4 plants with the amount of expenses authorized for recovery
in base rates in the applicable deferral year, and defer the difference from that currently
authorized. The deferral wil occur annually, with no carrying charge, with detèrrd costs
being amortized over a three-year period, beginning in January of the year following the
period costs are deferred. The amount of expense to be included for recovery in future
general rate caes would be the actual O&M expense recorded in the test period, less any
amount deferred during the test period, plus thc amortization of previously deferred costs.
The Company would defer the operations and maintenance expenses referenced
above in Account 182.3 .~ Other Regulatory Assets. 1be deferrals would be allocated to
the Idao and Washington jurisdictions based on the Production I Transmission allocation
percentages in place at the time the deferrls are made, and placed in separate Idaho and
Washington sub~accounts. Account 182.3 - Other Regulatory Assets would be debited,
and Account 401.4 - Regulatory Credits wil be credited as the deferrals are recorded.
Amonization wil be recorded by debiting Account 407.3 ~ Regulatory Debits, and
crediting Account 182.3 ~- Other Regulatory Assets.
STIPULATION AND SETTLEMENT - AVlJ-E/G-l 1-01 Page 9
iv. OTHER GENERA PROVISIONS
15. The Paries agree that this Stipulation represents a compromise of the positions of
the Parties in this ca'\c. As provided in RP 272, other than any testimony filed in support of the
approval of this Stipulation, and except to the extent necessary for a Pary to explain before the
Commission its OW11 statements and positions with respect to the Stipulation, an statements made
and positions taken in negotiations relating to this Stipulation shall be confidential and will not
be admissible in evidence in this or any other proceeding.
16. The Paries submit this Stipulation to the Commission and recommend approval
in its entirety pursuant to RP 274. Parties shaH support this Stipulation before the Commission,
and no Pary shall appeal a Commssion Order approving the Stipulation or an issue resolved by
the Stipulation. If this Stipulation is challenged by any person not a pary to the Stipulation, the
Paries to this Stipulation reserve the right to file testimony, cross~examine \vitnesses and put on
such case as they deem appropriate to respond fully to the issues presented, including the right to
raise issues that are incorprated in the settlement terms embodied in this Stipulation.
Notwithstanding this reservation of rights, the Parties to this Stipulation agree that they wil
continue to support the Commission's adoption ofthe terms of this Stipulation.
i 7. If the Commission rejects any par or all of this Stipulation or imposes any
additional material conditions on approval of this Stipulation, each Party reserves the right, upon
n.Titten notice to the Commssion and the other Parties to this proceeding, within 14 days of the
date of such action by the Commission, to withdraw from this Stipulation. In such case, no Pary
shall be bound or prejudiced by the terms of this Stipulation, and each Part shall be entitled to
seek reconsideration of the Commission's order,fie testimony as it chooses, cross-examine
witnesses, and do all other things necessary to put on such case as it deems appropriate. In such
STIPULATION AND SETTLEMENT ... AVU-E/G-I1-01 Page 10
case, the Paries immediately wil request the prompt reconvening of a prehearing conference for
puroses of establishing a procedural schedule for the completion of the case. The Paries agree
to cooperate in development of a schedule that concludes the proceeding on the earliest possible
date, takng into account the needs of the Paries in participating in hearngs and preparng
testimony and briefs.
18. The Paries agree that this Stipulation is in the public interest and that all of its
tenns and conditions are fair, just and reasnable.
19. No Party shaH be bound, benefited or prejudiced by any position asserted in the
negotiation of this Stipulation, except to the extent expressly stated herein, nor shall this
Stipulation be constued as a waiver of the rights of any Pary unless such rights are expressly
waived herein. Execution of this Stipulation shall not be deemed to constitute an
acknowledgment by any Party of the validity or invalidity of any particular method, theory or
principle of regulation or cost recovery. No Party shall be deemed to have agreed tht any
method, theory or principle of regulation or cost recovery employed in ariving at this Stipulation
is appropriate for resolving any issues in any other proceeding in the future. No findings of fact
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
20. The obligations of the Paries under this Stipulation are subject to the
Commission's approval of this Stipulation in accordance with its terms and conditions and upon
such approval being upheld on appeaL, if any, by a cour of competent jurisdiction.
21. 'I'his Stipulation may he executed in counterpars and each signed counterpart
shall constitute an original ducument.
STIPULATION AND SETTLEMENT - A VU-E/G-11-0 1 Page 11
138/26/21311 88: 03 20S3344Ð45
,~DATED ths :i day of Augus, 20 i 1.
A "vista. Corpration
By: ¡¡¡4'
Attorney fOOf Avista Corpration
Clearter Papr Corpration
By:
Peter Richarson
Attorny for Cleaiter Paper
Comunity Action Parrsip Association
By:
Bra M. Purd
Attorney for CAP AI
By:
¡PUC PAGE 131/02
Donald L. Howell, n
Weldon Stutzan
Deputy Attorn Geeral
Idaho Fore Grup
B)'~
Dean J. Miler
Attorey for Idaho Forest Group LtC
By:
Idaho Consrvation League
STIPULATION AND SETTLEMEN - A VU-EiG-I1-0 I
Beqjamn J. Ot
Attorney for rct
Page 12
DATED this _"_ day of August, 2011.
Avista Corpration
By;
David J. Meyer
Attrney for A vista Corporation
Peter Richadson
Attorney for Cleaater Paper
Communty Acton Parrship Asiation
By:
Bra M. Purdy
Attorny for CAP AI
Idao PubHc Utilties Commission Sta
By;
Donald L. HoweB, II
Krste A. Sassr
Deuty Attornys Geeral
Idaho Forest Group
By;
Dean J. Miller
Attorney for Idaho Forest Grup LLC
Idao Consrvation Lea.gue
By:
Bejamin 1. Oto
Attorny fòr reL
STIPULTION AND SETTLEMENT - AVU-ElG-ll-01 Page 12
DATBD this _ day of Augu, 2011.
A vista Corpration
By:
David J, Meyer
Attomcy for Avista Corporation
Clearater Paper Corporation
By:
Peter Richarson
Attrney for Clearater Paper
Communty Action Partnerhip Association
By:
Bra M. Purdy
Attorney for CAPAI
Idaho Public Utilties Commission Staff
By:
Donald L. Howen, n
Kristine A. Sasser
Deputy Attomeys General
1. Miner
Attorney for Idaho Foret Grup LLC
Idaho Conservation League
By:~
Benjamin J. Otto
STIPULATION AND SETTLEMENT - A VU-FJG-l1 ~O i Page 12
DATED ths ,___ day of Aug 2011.
Avist Corpration
By:
David J. Meyer
Attrny for A vist Corpation
Cleater Pap Corpration
By:
Peter Richadsn
Attorny for Clear Papr
Commun Action Parp Assiaon
Bra M. Pudy
Attorey for CAP AI
Idaho Public Utilities Commission Staff
Dona L. Howell, n
Weldon Stu
Dety Attorns Geer
Ida Forest Grup
By:
DeanJ.Miler
Attrney for Idaho Foret Grup LLC
Idao Consrvation Leage
By:
Bejamin J. Ot
Attorney for ICt
STIPULA nON AND SETn.EMENT - AVtJ-ElG-11-Ol Pagl
DATED thiS~ day of August, 20 i i.
A vista Corporation
By:
David 1. Meyer
Attorney for A vista Corporation
Clearater Paper Corporation
By:
Peter Richardson
Attorney for Clearater Paper
Community Action Partnership Association
By:
Brad M. Purdy
Attorney for CAP AI
Idaho Public Utilties Commission Staff
By:
Donald L. Howell, II
Weldon Stutzan
Deputy Attorneys General
Idaho Forest Group
By:
Dean J. Miler
Attorey for Idaho Foret GroupLLC
Idaho Co"ation League
By: ~ a&
Benjamin J. Oto
Attorney for ICL
STIULATION AND SETTEMENT - A VU-ElG-11-01 Page 12
STIPULATION AND SETTLEMENT
Case Nos. AVU-E-ll-Ol & AVU-G-ll-Ol
ATTACHMENT A
Summary of Proposed Net Rate Changes
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$
38
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0
0
0
$
(6
,
2
2
5
,
7
2
7
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6
8
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3
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1
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1
T
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t
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l

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5
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9

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e
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l

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x
c
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6
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6

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8
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R
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t
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9
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o
t
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l

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h
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10 11

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12

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13

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9

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6

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24 25 26

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t
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l

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a
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1
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6
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t
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l

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i
l
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d

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e
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e
$
68
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5
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3
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0
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4
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v
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h
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5
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n
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3
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39
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2
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e

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5
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/
1
5
5

-

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G
A

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n
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e
a
s
e
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77
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9
0
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58
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20
8
,
2
6
5
$
(1
8
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h
e
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e

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9
1
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M

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e
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e
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24
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6
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%
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t
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l

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1
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s
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9
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1
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1
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0
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1
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23

*

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s

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d

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n

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9
9

t
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,

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n
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24

*
*

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1

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1
Av
i
s
t
a
Pa
g
e

2
o
f
2
STIPULATION AND SETTLEMENT
Case Nos. AVU-E-II-01 & AVU-G-II-Ol
ATTACHMENT B
Electric PCA Authorized Expense and
Retail Sales
Av
i
s
t
a
C
o
r
p
Pr
o

f
o
r
m
a

J
a
n
u
a
r
y
.

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e
c
e
m
b
e
r
PC
A

A
u
t
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r
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z
e
d

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x
p
e
n
s
e

a
n
d

R
e
t
a
i
l

S
a
l
e
s
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A

A
u
t
h
o
r
i
z
e
d

P
o
w
e
r

S
u
p
p
i
Y

E
x
p
e
n
s
e

-

S
y
s
t
e
m

N
u
m
b
e
r
s

1
1
\
To
t
a
l
Ja
n
u
a
r
y
Fe
b
r
u
a
r
y
Ma
r
c
l\
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Ju
n
e
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Au
g
u
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t
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p
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b
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r
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t
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b
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r
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v
e
m
b
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r
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c
m
b
e
r
Ac
c
u
n
t

5
5
5

-

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u
r
c
a
s
e
d

P
o
w
r
$9
0
,
3
4
9
,
5
6
5

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1
0
,
1
2
2
,
5
0
7
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,
5
7
7
,
6
6
4
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,
0
1
9
,
0
8
5
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,
5
5
4
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8
4
3
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,
2
2
8
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9
4
6
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,
4
8
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1
6
9
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,
0
8
6
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9
7
1
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,
2
3
5
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4
6
3
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,
5
4
1
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7
3
1
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,
4
4
7
,
4
1
0
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,
5
4
1
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5
4
3
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,
5
0
6
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2
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2
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u
n
t

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0
1

-

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h
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r
m
a
l

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u
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l
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2
,
0
4
0

,
4
5
2
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0
7
2
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8
6
8
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7
8
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3
8
7
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9
7
4
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6
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5
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2
9
2
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1
0
6
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,
5
9
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7
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1
9
6
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6
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4
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8
1
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5
1
7
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1
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4
6
4
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0
3
2
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5
0
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,
0
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7
3
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c
u
n
t

5
4
7

-

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a
t
u
r
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l

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a
s

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u
e
l
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2
,
2
8
6
,
6
5
3
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9
7
7
,
0
1
0
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8
0
9
,
3
7
5
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6
9
9
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9
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5
5
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0
6
7
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5
2
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5
7
0
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8
2
6
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8
8
1
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,
0
0
6
,
9
5
2

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1
0
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0
1
6
,
4
8
6
$9
,
9
6
6
,
8
7
9

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1
1
,
6
4
5
,
5
9
9

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1
1
,
6
1
0
,
9
7
4

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1
1
,
6
5
3
,
0
2
3
Ac
c
u
n
t

44
7

-

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a
l
e

f
o
r

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e
s
a
l
e
$4
0
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3
5
1
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7
1
3
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5
5
5
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9
5
9
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4
2
8
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2
8
4
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3
4
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8
0
6
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9
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4
4
1
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,
5
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3
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5
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8
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4
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5
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3
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5
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2
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5
5
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2
9
6
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9
5
5
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7
6
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9
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,
7
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8
2
0
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w
e
r

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u
p
p
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y

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x
p
e
n
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e
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7
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9
5
6

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1
9
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1
6
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4
2
6

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1
7
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7
4
1
,
1
4
3

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1
5
,
3
4
4
,
7
6
2
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,
4
7
7
,
5
7
4
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,
7
7
1
,
3
0
9
$5
,
9
7
6
,
8
8
6

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1
1
,
4
5
4
,
9
0
8

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2
0
,
0
4
4
,
2
7
8

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1
4
,
9
7
1
,
8
3
0

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Case Nos. AVU-E-ll-01 & AVU-G-ll-Ol
ATTACHMENT C
Electric and Natural Gas Rate Design
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4
AVISTA UTILITIES
IDAHO ELECTRIC, CASE NO. AVU-E-11-01
PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE
Present General Billng Proposed Proposed
Base Tariff ERM&Present Rate Rate Biling Base Tariff
Sch. Rate Other Adj. (1 Biling Rate IncJ(Decr)Decrease (2)Rate Rate
(a)(b)(c)(d)(e)(f)(g)(h)
Residential Service. Schedule 1
Basic Charge $5.00 $5.00 $0.25 $5.25 $5.25
Energy Charge:
First 600 kWhs $0.07775 $0.00128 $0.07903 $0.0073 ($0.00287)$0.07689 $0.D848
All over 600 kWhs $0.08691 $0.00128 $0.08819 $0.00073 ($0.00287)$0.08605 $0.08764
General Services. Schedule 11
Basic Charge $9.50 $9.50 $0.50 $10.00 $10.00
Energy Charge:
First 3,650 kWhs $0.09063 $0.00476 $0.09539 $0.00275 ($0.00207)$0.09607 $0.09338
All over 3,650 kWhs $0.07731 $0.00476 $0.08207 ($0.00773)($0.00207)$0.07227 $0.06958
Demand Charge:
20 kWor less no charge no charge no charge no charge
Over 20 kW $4.75/kW $4. 75/kW $0.50/kW $5.25/kW $5.25/kW
Large General Servce - Schedule 21
Energy Charge:
First 250,000 kWhs $0.06109 $0.00393 $0.06502 ($0.00070)($0.00198)$0.06234 $0.06039
All over 2 (2) Includes all presen $0.05214 $0.00393 $0.05607 ($0.00060)($0.00198)$0.05349 $0.05154
Demand Charge:
50 kWor less $325.00 $325.00 $25.00 $350.00 $350.00
Over 50 kW $4. 25/kW $4. 25/kW $0.50/kW $4.75/kW $4.75/kW
Primary Voltage Discount $0.20/kW $0.20/kW $0.20/kW $0.20/kW
Extra Large General Servce. Schedule 25
Energy Charge:
First 500,000 kWhs $0.05065 $0.00447 $0.05512 ($0.00018)($0.00283)$0.5211 $0.05047
All over 500,000 kWhs $0.04290 $0.00447 $0.04737 ($0.00015)($0.00283)$0.04439 $0.04275
Demand Charge:
3,000 kva or less $12,000 $12,000 $500 $12,500 $12,500
Over 3,000 kva $4.00/kva $4.00/kva $0.50/kva $4.50/kva $4.50/kva
Primary Volt. Discount $0.20IkW $0.20/kW $0.20/kW $0.20/kW
Annual Minimum Present:$662,400 $666,570
Clearwter. Schedule 25P
Energy Charge:
all kWhs $0.04166 $0.00485 $0.04651 ($0.00020)($0.00326)$0.04305 $0.04146
Demand Charge:
3,000 kva or less $12,000 $12,000 $500 $12,500 $12,500
Over 3,000 kva $4.00/kva $4.00/kva $0.50/kva $4.50/kva $4.50/kva
Primary Volt. Discunt $0.20/kW $0.20/kW $0.20/kW $0.20/kW
Annual Minimum Present:$602,260 $606,060
Pumping Service. Schedule 31
Basic Charge $7.50 $7.50 $0.50 $8.00 $8.00
Energy Charge:
First 165 kW/kWh $0.08852 $0.00227 $0.09079 $0.00087 ($0.00074)$0.09092 $0.08939
All additional kWhs $0.07546 $0.00227 $0.07773 $0.00074 ($0.00074)$0.07773 $0.07620
(1) Includes all present rate adjustments: Scheckle 59 - Residential & Farm Energy Rate Adjustment, Schedule 66 - Temporary
Power Cost Adjustment, Schedule 91 - Energy Effciency Rider Adjustment, and Schedule 99 - Deferred State Income Tax
Adjustment.
(2) Includes proposed rate adjustments: Schedule 59 - Residential & Farm Energy Rate Adjustment, Schedule 66 - Temporary Power
Cost Adjustment, and Schedule 99 - Deferred State Income Tax Adjustment.
Stipulation and Settlement
Case No. AVU-E-11-01 and AVU-G-11-01
Avista
Attachment C Page 2 of4
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4
AVISTA UTILITIES
IDAHO GAS, CASE NO. AVU-G-11-Ð1
PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE
General Proposed Other Proposed Proposed
Base Present Present Rate PGA-Gas Cost Rate Billng Base
Rate (1)Rate Adj.(2) Biling Rate ~B!Change (2)Rate (2)Rate (1)
(a)(b)(c)(d)(e)(f)(g)(h)(i)
General Service - Schedule 101
Basic Charge $4.00 $4.00 $0.25 $4.25 $4.25
Usage Charge:
All therms $0.94102 ($0.02649)$0.91553 $0.0656 ($0.3106)$0.01603 $0.90706 $0.91652
Large General Service - Schedule 111
Usage Charge:
First 200 therms $0.96103 ($0.02905)$0.93198 $0.00272 ($0.03106)$0.0970 $0.91334 $0.93269
200 - 1,000 t herms $0.82865 ($0.02905)$0.79960 $0.00889 ($0.03106)$0.00970 $0.78713 $0.80648
1,000 - 10,000 therms $0.75404 ($0.02905)$0.72499 $0.00763 ($0.3106)$0.00970 $0.71126 $0.73061
All over 10,000 tharms $0.70488 ($0.02905)$0.67583 $0.00680 ($0.03106)$0.00970 $0.66127 $0.68062
Minimum Charge:
per month $79.03 $79.03 $1.56 $80.59 $80.59
per therm $0.56587 ($0.02905)$0.53682 ($0.00508)($0.03106)$0.00970 $0.51038 $0.52973
Interruptible Service. Schedule 131
Usage Charge:
All Therms $0.62748 ($0.04357)$0.58391 $0.00471 ($0.03796)$0.01903 $0.56969 $0.59423
Transportation Service - Schedule 146
Basic Charge $200.00 $200.00 $25.00 $225.00 $225.00
Usage Charge:
All Therms $0.10559 ($0.00159)$0.10400 $0.0112 $0.00159 $0.10671 $0.10671
(1) Includes Schedule 150 - Purchas ed Gas Cost Adjustment
(2) Includes Schedule 155 - G as Rate Adjustment, Schedule 191 - Energy Effciency Rider Adjustment and Schedule 199. Deferred State Income
Tax Adjustment
Attachment C
Stipulation and Settement
Case No. AVU-E-11-0tand AVU-G-11-01
Avista
Page 4 of4