20151202Transcript Exhibits Volumes I & II.pdf

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IL oRtcrNAL il
BEFORE THE IDAHO PUBLIC
!.-urrlrrrEs com,rffiT*-*
IN THE MATTER OF THE APPLICATION
OF AVISTA CORPORATION DBA AVISTA
UTILIT]ES FOR AUTHORITY TO
INCREASE ITS RATES A}ID CHARGES FOR
ELECTRIC AND NATURAL GAS SERVICEIN ]DAHO
)
) CASE
) CASE
)
)
)
)
NO . AW-E- 15- 0 5No. av]u-e-1s-01
EXHIBITS
BEEORE
COMMISSIONER KRISTINE RAPER (Presiding)_
COMMISSIONER MARSHA SMITH L5
COMMISSIONER PAUL KJELLANDER T_Icr€\
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PLACE:Commission Hearing Room fF,
412 West Washington Street
=*Bo j- se, rdaho - oo(" '
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DATE: November 23, 201.5
VOLUMES I & II Pages 1- - !21
CSB REPORTING
Constance S. Bucy, CSRNo. 187
23876 Applewood Way * Wildeq Idaho 83676
(208) 890-sle8
Ernail csb@heritagewifi . com
DAVID r. ?ili H$v t3 All g: 5VICE PRESIDENT AND CHIEF COUNSEL FOR ."
REGULATORY & GOVERNMENTAL AEFATRS ln,,q,t_is L,j.jliLlc
AVTSTA CoRPORATTON U'illl',iii:$ c0MMi$siiP.O. BOX 3727
L41T EAST MISSION AVENUE
SPoKANE, WASHTNGTON 99220-3127
TELEPHONE: [phone]L6
FACSIMILE: [phone]
DAVI D . MEYERGAVI STACORP . COM
BEE'ORE THE IDAIIO PUBLIC T'TII,IUES COMMISSION
IN THE MATTER OF THE APPLICATION
OF AVISTA CORPORATION FOR THE
AUTHORITY TO INCREASE ITS RATES
AND CHARGES EOR ELECTRIC AND
NATURAL GAS SERVICE TO ELECTRIC
AND NATURAL GAS CUSTOMERS TN THE
STATE OE IDAHO
CASE NO. AVU-E-15-05
CASE NO. AVU-G-15-01
EXH]BIT NO. 1
ELIZABETH M. ANDREWS
EOR AVISTA CORPORATION
(ELECTRIC AND NATURAL GAS)
David J. Meyer, Esq
Vice President and Chief Counsel of
Regulatory and Governmental Affairs
Avista Corporation
14l1 E. Mission Avenue
P.O.Box3727
Spokane, Washington 99220
Phone: [phone], Fax: [phone]
Karl Klein
Brandon Karpen
Deputy Attorneys General
Idaho Public Utilities Commission Staff
P.O. Box 83720
Boise,lD 83720-0074
Phone: [phone]l2,Fax: [phone]
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF AVISTA CORPORATION DBA AVISTA ) CASE NOS.
UTILITIES FOR AUTHORITY TO )
INCREASE ITS RATES AND CHARGES )
FOR ELECTRIC AND NATURAL GAS )
SERVICE IN IDAHO ) STIPULATION AI\D SETTLEMENT
This Stipulation is entered into by and among Avista Corporation, doing business as
Avista Utilities ("Avista" or "Company"), the Staff of the Idaho Public Utilities Commission
("Staff), Clearwater Paper Corporation ("Clearwater"), Idaho Forest Group, LLC ("Idaho
Forest"), the Community Action Partnership Association of Idaho ("CAPAI"), the Idaho
Conservation League ("ICL"), and the Snake River Alliance ("Snake River"). These entities are
collectively referred to as the "Parties," and represent all of the parties in the above-referenced
cases. The Parties understand this Stipulation is subject to approval by the Idaho Public Utilities
Commission ("IPUC" or the "Commission").
AW-E-ls-05
AVU-G-15-01
STIPI.]LATION AND SETTLEMENT _ AW.E.15-05 & AW-G-Is-OI Page I
I. INTRODUCTION
l. The terms and conditions of this Stipulation are set forth herein. The Parties agree
that this Stipulation represents a fair, just and reasonable compromise of all the issues raised in
the proceeding, is in the public interest and its acceptance by the Commission represents a
reasonable resolution of the multiple issues identified in these cases. 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.
II. BACKGROUNI)
2. On June 1,2015, Avista filed an Application with the Commission for authority
to increase revenue effective January 1,2016 for electric and natural gas service in Idaho by
5.2o/o and 4.5yo, respectively. If approved, the Company's 2016 revenues for electric base retail
rates would have increased by $13.2 million annually, and Company revenues for natural gas
service would have increased by $3.2 million annually. The Company also requested an increase
to electric base retail revenue of $13.7 million (5.1%), and an increase in natural gas base retail
revenue of $1.7 (2.2%), effective January 1,2017. By OrderNo.33324, dated June 15,2015,
the Commission suspended the proposed schedules of rates and charges for electric and natural
gas service.
3. Petitions to intervene in this proceeding were filed by Clearwater, Idaho Forest,
CAPAI, ICL, and Snake River. The Commission granted these interventions through IPUC
Order Nos. 33331 and 33338.
STIPULATION AND SETTLEMENT _ AW.E.I5.O5 & AW-G-I5-01 Page2
4. A settlement conference was noticed and held in the Commission offices on
September 18,2015, and was attended by signatories to this Stipulation.l Based upon the
discussions among the Parties, as a compromise of positions in this case, and for other
consideration as set forth below, the Parties agree to the following terms:
III. TERMS OF THE STIPULATION AI\ID SETTLEMENT
5. Overview of Settlement and Revenue Requirement. The Parties agree that Avista
should be allowed to implement revised tariff schedules designed to recover $1.7 million in
additional annual electric revenue, and $2.5 million in additional annual natural gas revenue,
which represent a 0.69Yo and 3.49Yo increase in electric and natural gas annual base tariff
revenues, respectively. New electric and natural gas rates would become effective January 1,
20t6.
6. Cost of Capital. The Settling Parties agree to a 9.5 percent retum on equity, with
a 50.0 percent common equity ratio. The capital structure and resulting rate of return is as set
forth below:
Comonent
Capital
Structue Cost Weiehted Cost
Debt
ConrnonEqutry
Total
50%
s0%
t00%
5.34o/o
9.50%
2.67%
4.75%
7.42o/o
I ICL was unable to attend the Settlement Conference; however, they did provide a "Position Statement" on
September 17 ,2015 providing their views on issues related to the proposed Fixed Cost Adjustrnent mechanisms and
rate design.
STIPI.]LATION AND SETTLEMENT - AW.E-15-05 & AW.G.Is-OI Page 3
A. ELECTRIC
7. Overview of Electric Revenue Requirement. Below is a summary table and
descriptions of the electric revenue requirement components agreed to by the Parties for January
1,2016:
SUMMARY TABLE OF'ADJUSTMENTS TO ELECTRIC REVENUE REQUIREMENT
EFFECTTVE JANUARY I, 2016
(000s ofDollars)
Revenue
Requircment Rate Base
Amount as Filed:
Adjustments:
Cost of Capital
) Revise 2015 Capital Additbns
.) Remove20l6CapalAdditions
d.) Revbe Deferred Debits and Credits to Refhct 2015 Balances
e.) Remove 2016 Expenses
i. Insurance Expense
ii. Informatbn Services & Technolory
iii. Non-ExecutiveLabor
iv. O&M Offsets
t) Update 2015 Empbyee Beneflt Costs
Adjust Injuries and Damage s Expense
h.) Remove Offrcer Incentives and Restate Non-Officer Incentive s
i.) Inchrde Four-Year Amortizatbn of 2015 Project Compass Deferral
Inchde Fou-Year Amortizatbn of Lake Spokane Defenal
) Inchrde Pahr.ue Wind inPCA
) Miscellaneous A&GAdjustnents: Director & Offlrcer Insurance, Board of
Dbector Expenses, Realbcatbn of Legal Expenses, Removal of Environmental
Cbanup Costs, and Removal of Miscelhneous Agree&To Expenses
Adjusted Amounts Efrective January 1,2016
$ 13,230 $ 749,225
$
$
$
$
(2,438)
(3,345) $ (l
(548) $ 1,789
52 $ l3l
(62)
(521)
(385)
212
481
(8)
(100)
(66e)
(ile)
(3,500)
$
$
$
$
$
$
$
$
$
$
$ (580)
$ 1,700 $
Cost of Capital. As previously described (see Paragraph 6 above). This adjustment
reduces the overall revenue requirement by $2.438 million.
Revise 2015 Capital Additions. Reflects adjustments to updated information related
to 2015 capital additions, including the delay in completion of the Nine Mile
Hydroelectric Capital Project from 2015 to 2016 and the impact on depreciation
expense, as well as accumulated depreciation (A/D) and accumulated deferred federal
b.
STIPULATION AND SETTLEMENT _ AVU.E-I5-05 & AW-G.l5-OI Page 4
c.
income taxes (ADFIT). This adjustment reduces the overall revenue requirement by
$3.345 million and reduces rate base by $16.125 million.
Remove 2016 Capital Additions. Reflects the removal of proposed 2016 capital
additions) and related depreciation expense, as well as the impact on A/D and
ADFIT. This adjustment reduces the overall revenue requirement by $548,000 and
increases rate base by $1.7S9 million2.
Revise Deferred Debits and Credits. Revises the deferred debits and credits
regulatory balances to reflect balances as of December 2015, rather than the 2016
balances as proposed by the Company. This adjustment increases the overall revenue
requirement by $52,000 and increases rate base by $131,000.
Remove 2016 Expenses. These adjustments remove 2016 incremental expenses or
offsets as proposed by the Company, including:
i. lnsurance Expense - This adjustment reduces the overall revenue
requirement by $62,000, by removing20l6 incremental expenses.
ii. Information Services & Technology - This adjustment reduces the overall
revenue requirement by $521,000, by removing 2016 incremental
lv.
expenses.
Non-Executive Labor - This adjustment reduces the overall revenue
requirement by $385,000, by removing 2016 incremental expenses.
O&M Offsets - This adjustment increases the overall revenue requirement
by $212,000, by removing 2016 offsets related to 2016 capital additions
removed in sub-paragraph c. above.
d.
e.
Iil.
2 Removing the impact of 2016 capital additions, as well as removing the impact on accumulated depreciation and
accumulated deferred federal income taxes on total net plant during 2016, has the result ofincreasing overall net rate
base.
STTPULATION AND SETTLEMENT _ AW-E-I5-05 & AVU.G.l5-OI Page 5
Update 2015 Employee Benefit Costs. Reflects updated information related to 2015
incremental pension and medical costs. This adjustment increases the overall revenue
requirement by $481,000.
Adjust lniuries and Damages Expense. Revises the six-year average of injuries and
damages. This adjustment decreases the overall revenue requirement by $8,000.
Remove Officer lncentives and Restate Non-Officer Incentives. Reflects the removal
of officer incentives and adjusts the non-officer incentive six-year average from a
102% to a 100%o payout. This adjustment decreases the overall revenue requirement
by $100,000.
Include Four-Year Amortization of 2015 Project Compass Deferral. Revises the two-
year amortization of the 2015 Project Compass Deferral, as proposed by the
Company, to a four-year amortization. This adjustment decreases the overall revenue
requirement by $669,000.
Include Four-Year Amortization of Lake Spokane Deferral. Revises the two-year
amortization of the Lake Spokane Deferral, as proposed by the Company, to a four-
year amortization. This adjustment decreases the overall revenue requirement by
$l19,000.
Include Palouse Wind in PCA. Reflects the removal of the Palouse Wind Power
Purchase Agreement net expenses from base power supply expense. This adjustment
decreases the overall revenue requirement by $3.5 million. See Paragraph 8 below
for further information related to Palouse Wind.
l. Miscellaneous A&G Adjustments. Reflects the removal of net administrative and
general (A&G) expenses related to: 1) removing an additional 40o/oof Idaho electic
Director and Officer insurance expense ($114,000); 2) removing legal expenses
ob'
h.
J.
k.
STIPULATION AND SETTLEMENT _ AW-E-I5-05 & AW.G-15-OI Page 6
allocated to Idaho electric in error ($5,000); 3) removing 213 of environmental
cleanup expenses incurred in 2014 ($322,000); 4) removing miscellaneous expenses
as agreed to ($65,000); and removing additional Board of Director expenses included
in 2014 ($74,000). This adjustment decreases the overall revenue requirement by
$580,000.
8. Palouse Wind. The Parties agree that, for purposes of this case, the recovery of
costs related to the Palouse Wind Power Purchase Agreement ("PPA") will continue to be
included in the PCA, subject to the current sharing (90% customeg l|Yo Company).
B. NATURAL GAS
9. Overview of Natural Gas Revenue Requirement. Below is a summary table and
descriptions of the Natural Gas revenue requirement components agreed to by the Parties:
SUMMARY TABLE OF ADJUSTMENTS TO NATURAL GAS REVENUE REQUIREMENT
EFFECTIVE JANUARY 1, 2016
(000s ofDollan)
Revenue
Requirement Rate Base
Amount as Filed: $ 3,205 $ 127,498
Adjustments:
a.) Cost of Capital S (415)
b.) Revise 2015 CapitalAdditions $ 440 $ 3,758
.) Remove 2016 Capital Additions $ (76) $ 669
) Revise Defened Debits and Credits to Reflect 2015 Balances $ (3)
Remove 2016 Experses
i. Insurance Expense $ (16)
ii. lnformation Services & Technology $ (132)
iii. Non-Executive Labor $ (185)
[) Update 2015 Employee Benefr Costs $ 129
) Adjust Injurbs and Damages Expense $ (126)
) Remove Officer Incentives and Restate Non-Officer Incentives $ (25)
) Inchrde Four-Year Amortization of 2015 Project Compass Deferral $ (168)
i.) Miscellaneous A&G Adjusfrnents: Director & Officer Insurance, Board of
Director Expenses, Reallocation of kgal Expemes, and Removal of
Miscellaneous Agreed-To Expenses $ (128)
Adjusted Amounts Effective January 1,2016 $ 2,500 $ 131,925
STIPULATION AND SETTLEMENT - AVU-E-I5-05 & AVLi-G-I5-01 Page 7
b.
a. Cost of Capital. As previously described (see Paragraph 6 above). This adjustment
reduces the overall revenue requirement by $415,000.
Revise 2015 Capital Additions. Reflects adjustments to updated information related
to 2015 capital additions and the impact on depreciation expense, as well as AID and
ADFIT. This adjustment increases the overall revenue requirement by $440,000 and
increases rate base by $3.758 million.
Remove 2016 Capital Additions. Reflects the removal of proposed 2016 capital
additions and related depreciation expense, as well as the impact on A/D and ADFIT.
This adjustment reduces the overall revenue requirement by $76,000 and increases
rate base by $669,0003.
d. Revise Deferred Debits and Credits. Revises the deferred debits and credits
regulatory amortization expense to reflect 2015 expenses, rather than 2016 expense
levels as proposed by the Company. This adjustment decreases the overall revenue
requirement by $3,000.
e. Remove 2016 Expenses. These adjustments remove 2016 incremental expenses as
proposed by the Company, including:
i. Insurance Expense - This adjustment reduces the overall revenue
requirement by $16,000, by removing20l6 incremental expenses.
Information Services & Technology - This adjustment reduces the overall
revenue requirement by $132,000, by removing 2016 incremental
expenses.
Non-Executive Labor - This adjustment reduces the overall revenue
requirement by $185,000, by removing20l6 incremental expenses.
c.
tid
STIPULATION AND SETTLEMENT _ AW-E.I5.05 & AW-G-Is-OI Page 8
Update 2015 Employee Benefit Costs. Reflects updated information related to 2015
incremental pension and medical costs. This adjustment increases the overall revenue
requirement by $129,000.
Adiust Injuries and Damages Expense. Revises the six-year average of injuries and
damages. This adjustment decreases the overall revenue requirement by $ 126,000.
Remove Officer Incentives and Restate Non-Officer Incentives. Reflects the removal
of officer incentives and adjusts the non-officer incentive six-year average from a
102% to a l00Yo payout. This adjustment decreases the overall revenue requirement
by $25,000.
Include Four-Year Amortization of 2015 Project Compass Deferral. Revises the two-
year amortization of the 2015 Project Compass Deferral, as proposed by the
Company, to a four-year amortization. This adjustment decreases the overall revenue
requirement by $168,000.
j. Miscellaneous A&G Adjustments. Reflects the removal of net administrative and
general (A&G) expenses related to: 1) removing an additional 40Yo of Idaho Director
and Officer insurance expense ($29,000); 2) removing legal expenses allocated to
Idaho natural gas in error ($1,000); 3) removing miscellaneous expenses as agreed to
($79,000); and removing additional Board of Director expenses included in 2014
($19,000). This adjustnent decreases the overall revenue requirement by $128,000.
C. OTIIE,R SETTLEMENT COMPONENTS
12. PCA Authorized Level of Expense. The new level of power supply revenues,
expenses, retail load and Load Change Adjustment Rate resulting from the January l, 2016
(}b.
h.
STIPULATION AND SETTLEMENT _ AW.E. I 5.05 & AVU-G- I 5-O I Page 9
settlement revenue requirement for purposes of the monthly PCA mechanism calculations are
detailed in Appendix A.
13. Fixed Cost Adjustment Mechanism. The Parties agree that Avista will implement
electic and natural gas Fixed Cost Adjustment mechanisms ("FCA"). The electric and natural
gas FCAs are illustrated in Appendices B and C and will commence concurrently with the
natural gas and electric rate changes January I,2016. Below are the key components of the
mechanisms:
A. FCA Mechanisms Term. The Parties agree to an initial FCA term of 3 years, with a
review of how the mechanisms have functioned conducted by Avista, Staff, and other
interested parties following the end of the second full-year. Avista may seek to extend
the term of the mechanism prior to its expiration.
B. Rate Groups. There will be two rate groups established for both the electric FCA and
natural gas FCA:
Electric Customer Rate Groups:
l. Residential - Schedule 1
2. Commercial - Schedules I l, 12,21,22,31,32
Natural Gas Rate Groups:
l. Residential - Schedule 101
2. Commercial - Schedules 111 and 112
C. Existing Customers and New Customers. The Parties have agreed that revenue
related to certain items discussed below would not be included in the FCA for new
customers. The result is that the Fixed Cost Adjustment Revenue-Per-Customer for new
customers will be less than the Fixed Cost Adjustment Revenue-Per-Customer for
existing customers. For new electric customers added after the test period, recovery of
STIPULATION AND SETTLEMENT - AVU.E-I5.05 & AW-G-Is-OI Page 10
incremental revenue related to fixed production and transmission costs would be
excluded from the electric FCA. For new natural gas customers added after the test
period, recovery of incremental revenue related to fixed production and underground
storage facility costs would be excluded. These modifications are included in Appendices
B and C to the Stipulation.
D. Ouarterly Reporting. Avista will file, within 45 days of the end of each quarter, a
report detailing the FCA activity by month. The reporting will also include information
related to the deferrals by rate group, what the deferrals would have been if racked by
rate schedule, use and revenue-per-customer for existing and new customers, and other
summary financial information. Avista will provide such other information as may be
reasonably requested, from time to time, in the future quarterly reports.
E. Annual Filings. On or before July 1, the Company will file a proposed rate
adjustment surcharge or rebate based on the amount of deferred revenue recorded for the
prior January through December time period. The rate adjustment would be calculated
separately for each Rate Group, with the applicable surcharge or rebate recovered from
each group on a uniform cents per kWh or per therm basis. The proposed tariff
(Schedule 75 for electric, Schedule 175 for natural gas) included with that filing would
include a rate adjustment that recovers/rebates the appropriate deferred revenue amount
over a twelve-month period effective on October 1 for electic (to match with Power Cost
Adjustment and Residential Exchange annual rate adjustments time period) and
November I't for natural gas (to match with the annual Purchased Gas Cost Adjustment
rate adjustment time period). The deferred revenue amount approved for recovery or
rebate would be transferred to a balancing account and the revenue surcharged or rebated
during the period would reduce the deferred revenue in the balancing account. After
STIPULATION AND SETTLEMENT _ AVU-E-15-05 & AW.G-l5-OI Page I I
determining the amount of defered revenue that can be recovered through a surcharge
(or refunded through a rebate) by Rate Group, the proposed rates under Schedules 75 and
175 would be determined by dividing the deferred revenue to be recovered by Rate
Group by the estimated kWh sales (Elecfric FCA) or therm sales (Natural Gas FCA) for
each Rate Group during the twelve-month recovery period. Any deferred revenue
remaining in the balancing account at the end of the amortization period would be added
to the new revenue deferrals to determine the amount of the proposed surcharge/rebate
for the following year.
F. Interest. lnterest will be accrued on the unamortized balance in the FCA balancing
accounts at the Customer Deposit Rate.a
G. Accounting. Avista will record the deferral in account 186 - Miscellaneous Deferred
Debits. The amount approved for recovery or rebate would then be transferred into a
Regulatory Asset or Regulatory Liability account for amortization. On the income
statement, the Company would record both the defened revenue and the amortization of
the deferred revenue through Account 456 (Other Electric Revenue), or Account 495
(Other Gas Revenue), in separate sub-accounts. The Company would file quarterly
reports with the Commission showing pertinent information regarding the status of the
current deferral. This report would include a spreadsheet showing the monthly revenue
deferral calculation for each month of the deferral period (January - December), as well
as the current and historical monthly balance in the deferral account.
a Based on Order No. 33187 in Case No. GNR-U-14-L2,the deposit rate for 2015 is l.0o/o.
annually.
STIPULATION AND SETTLEMENT - AW.E.I5-05 & AW-G.l5-OI
The rate is updated
Page 12
H. 3oZ Rate Increase Cap. An FCA surcharge, by rate goup, cannot exceed a3o/o annual
rate adjustment, and any unrecovered balances will be carried forward to future years for
recovery. There is no limit to the level of the FCA rebate.
D. COST OF SERYICEIRATE SPREAD/RATE DESIGN
14. Cost of Service. For electric operations, the Company prepared an analysis using
a system load factor peak credit method of classifying production costs, allocating 100% of
transmission costs to demand, and allocating transmission costs on a twelve-month basis. For
settlement purposes, the Parties agreed to use a pro-rata allocation based on the Company's
proposed 25oh move towards unity for purposes of spreading the revised electric revenue
requirement, while not agreeing on any particular cost of service methodology.
For natural gas operations, the Company proposed that all rate schedules be moved
approximately 33Yo towards unity. For settlement purposes, the Parties agreed to use a pro-rata
allocation of the Company's natural gas rate spread percentages from its original filing for
purposes of spreading the revised revenue requirement.
15. Rate Spread/Rate Design (Base Rate Changes).
(a) As indicated above, the Parties agreed that the increase in base revenues
would be spread to all electric and natural gas rate schedules on a pro-rata allocation of
the Company's rate spread percentages from its original filing.
(b) Electric Rate Design. The Parties agree that the revenue requirement for each
electic service schedule will be applied as a uniform percentage increase to each
volumetric energy rate as shown in Appendix D. Fixed monthly charges and fixed and
variable demand charges will remain unchanged. The electric Residential Basic Charge
STIPULATION AND SETTLEMENT _ AW-E-I5-05 & AW-G-I5-OI Page 13
(Schedule 1) will remain at $5.25 per month. Finally, the street and area light codes and
calculation methodology described in Mr. Ehrbar's direct testimony will be adopted.
(c) Natural Gas Rate Design. The Parties agree that the Basic Charge for
Schedule l0l will increase by $1.00 per month, from $4.25 to $5.25. The revenue
requirement for all other natural gas service schedules will be applied as a uniform
percentage increase to each volumetric energy rate as shown in Appendix D.
(d) Appendix D provides a summary of the current and revised rates and charges
(as per the Settlement) for electric and natural gas service.
16. Electric Rebate Extension. Through rate Schedule 97, customers are receiving a
rebate of $0.00091 per kWh for 2015 (approximately $2.8 million). This rebate rate was first
approved in the Company's 2012 general rate case, Case No. AVU-E-12-08. As a part of the
settlement stipulation approved by the Commission in Case No. AW-E-14-05, the rebate rate
was extended through December 31,2015 using the 2013 elecfic earnings sharing deferral. For
2014, Avista deferred approximately $5.6 million under the electric earnings sharing. The
Parties agree to use the $5.6 million deferral balance from 2014 and extend the Schedule 97
rebate rate for 2016 and20fis. This information is shown on Appendix E.
17. Natural Gas Rebate Extension. Through rate Schedule 197, customers are receiving
a rebate of $0.01489 per therm through December 31,2015 (approximately $1.2 million). This
rebate rate was first approved in the Company's 2012 general rate case, Case No. AVU-G-12-07.
As a part of the settlement stipulation approved by the Commission in Case No. AVU-G-14-01,
the rebate rate was extended for 2015 using the 2013 natural gas earnings sharing deferral, as
well as the Schedule l9l Natural Gas Energy Efficiency funding balance. For 2014, Avista
deferred approximately $0.2 million under the natural gas earnings sharing. The Company is
5 The electric and natural gas eamings sharing is in place for the2013-2015 rate plan.
STIPULATION AND SETTLEMENT _ AW-E-15-05 & AVU.G.Is-OI Page 14
proposing to use the $0.2 million natural gas deferral balance from 2014 to partially offset the
expiration of the $1.2 million rebate that will occur on January I,2016. This information is
shown on Appendix E.
18. Resulting Percentase Increase by Electric Service Schedule. The following tables
reflect the agreed-upon percentage increase by schedule for electric service:
Increase in Base Incrcase in
Rates Billins Rates
0.9%
0.5o/o
0.60/o
0.6%
0.4%
0.7%
0.8%
0J%
19. Resultine Percentage lncrease by Natural Gas Service Schedule. The following
tables reflect the agreed-upon percentage increase by schedule for natural gas service:
Rate Schedule
ResiCenthl Sctrcdule I
General Service Schedules 11/12
[,arge General Service Schedules 21122
E>ffa Iarge General Service Sclrcdule 25
Clearwater Paper Sctredule 25P
Purping Servbe Sctredules 31/32
Street & Area Lghts Schedules 4l-48
Overall
Rate Schedule
General Servbe Sctredule 101
large General Servbe Schedules llllll2
Intempt. Sales Servbe Scheduhs l3lll32
Billing Rates Expirine Rebate
09%
0.s%
0.6%
0.6%
0.4%
0.7%
0.8%
0.7o/"
Increase in
Base Rates
Increase in
Billing Increase
Net of New&
Transportation Service Schedule 146* 5.2%
Overall 6.9%
* excludes commodity and interstate pipeline transportation costs
7.7%
3.7%
7.5%
4.1%
r.5%
2.7%
5.2%
3,5!Y!
53%
3.t%
4.8%
3.1%
4.8o/"
20. CustomerService-Relatedlssues.
(a) Low-Income Usage Data. The Company and interested parties will meet and
confer prior to the Company's next general rate case in an effort to identifr low income
STIPULATION AND SETTLEMENT _ AVU.E. I 5-05 & AW.G- I 5-O I Page 15
customers served by the Company, quantify the number of customers so identified, and
determine those customers' usage patterns. An initial meeting shall occur no later than
June 30, 2016, with follow-up meetings to occur as the attendees may deem appropriate.
(b) Collaboration on Low-Income Weatherization. The Company and interested
parties will meet and confer prior to the Company's next general rate filing in order to
assess the Low lncome Weatherization and Low Income Energy Conservation Education
Programs and discuss appropriate levels of cost-effective, low-income weatherization
funding in the future. An initial meeting shall occur no later than June 30, 2016, with
follow-up meetings to occur as the attendees may deem appropriate.
TV. OTHER GENERAL PROYISIONS
21. The Parties agree that this Stipulation represents a compromise of the positions of
the Parties in this case. 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 Party to explain before the
Commission its own statements and positions with respect to the Stipulation, all 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.
22. The Parties submit this Stipulation to the Commission and recommend approval
in its entirety pursuant to RP 274. Parties shall support this Stipulation before the Commission,
and no Party shall appeal a Commission Order approving the Stipulation or an issue resolved by
the Stipulation. If this Stipulation is challenged by any person not a party to the Stipulation, the
Parties to this Stipulation reserve the right to file testimony, cross-examine witnesses and put on
such case as they deem appropriate to respond fully to the issues presented, including the right to
raise issues that are incorporated in the settlement terms embodied in this Stipulation.
STIPULATION AND SETTLEMENT - AW.E.I5-05 & AVU.G-Is.OI Page 16
Notwithstanding this reservation of rights, the Parties to this Stipulation agree that they will
continue to support the Commission's adoption of the terms of this Stipulation.
23. If the Commission rejects any part or all of this Stipulation or imposes any
additional material conditions on approval of this Stipulation, each Party reserves the right, upon
written notice to the Commission 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 Party
shall be bound or prejudiced by the terms of this Stipulation, and each Party shall be entitled to
seek reconsideration of the Commission's order, file testimony as it chooses, cross-examine
witnesses, and do all other things necessary to put on such case as it deems appropriate. In such
case, the Parties immediately will request the prompt reconvening of a prehearing conference for
purposes of establishing a procedural schedule for the completion of the case. The Parties agree
to cooperate in development of a schedule that concludes the proceeding on the earliest possible
date, taking into account the needs of the Parties in participating in hearings and preparing
testimony and briefs.
24. The Parties agree that this Stipulation is in the public interest and that all of its
terms and conditions are fair, just and reasonable.
25. No Party shall 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 construed as a waiver of the rights of any Party 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 that any
method, theory or principle of regulation or cost recovery employed in aniving at this Stipulation
is appropriate for resolving any issues in any other proceeding in the future. No findings of fact
STIPULATION AND SETTLEMENT - AW-E-I5-05 & AW-G.Is.OI Page 17
or conclusions of law other than those stated herein shall be demed to be implicit in this
Stipulation.
26. The obligations of the Parties under this Stipulation are subject to the
Commission's appncval of this Stipulation in accordance with its terms and conditions and upon
such approval being upheld on appeal, if any, by a court of competent jurisdiction.
27, This Stipulation may be executed in counteqparts and each signed counterpart
shall constitute an original document.
'uL4
DATED uii, !;(g-' {^yof october, 2o I 5.
Avista Corporation
for Avista Corporation
Clearwater Paper Corporation
By:
Peter Richardson
Attorney for Clearwater Paper
Conservation League
Bvl
Benjamin J. Otto
Attomey for ICL
Idaho Public Utilities Commission Staff
By:
Karl Klein
Brandon Karpen
Deputy Attorneys General
Fottst Group
By:
Idaho
Idaho
Dean J. Miller
Attorney for Idaho Forest Group LLC
Snake River Alliance
By;
KelseyNunez
Atorney for Snake RiverAllianoe
STIPULATION A}.ID SETTLEMENT - AW.E. 1 5.05 & AW-G-I 5-O 1 Page l8
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
26. The obligations of the Parties 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 coutt of competent jurisdiction.
27. This Stipulation may be executed in countetparts and each signed counterpart
shall constitute an original document.
DATED ttris ll4aay of October, 2015.
Avista Corporation
By:
David J. Meyet
Attorney for Avista Corporation
Clearwater Paper Corporation
Peter Richardson
Attorney for Clearwater Paper
Conseration League
Brandon Karpen
Deprty Attorneys General
Forest Group
Dean J. Milter
Attorney for Idaho Forest Group LLC
River Alliance
KelseyNunez
Attorney for Snake River Alliance
Idaho
By:BYI
Idaho Snake
By:By:
Benjamin J. Otto
Attorney forICL
Idaho Public Utilities Commission Staff
STIPULATION AND SETILEMENT _ AVU-8.15.05 & AVU.G.Is.OI Page 18
or conclusioftr of law other than those stated trcrein shall be deenred to be implicit in this
Stipulation.
26. The obligations of the Parties under this Stipulation are zubject to the
Commission's approval of this Stipulation in accordance with its terms and conditions and upon
zuch approval being upheld on appeal, if any, by a oourt of competent juidiction.
27. This Stipulation may be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED this _ day of October, 2015.
Avistr Corporation
By:
David J. Meyer
Attomey for Avista Corporation
Idaho
By:
Idaho Public Utilities Commission Staff
By:
Karl Klein
Brandon Karpetr
Deputy Attomeys General
Forest Group
By:
Idaho
BenjaminJ. Ofro
Auorney forICL
DeanJ. Miller
Attorney for Idaho Forest Group LLC
Snake RiverAlliance
By:
KelseyNunez
Attorocy for Snake River Alliance
PeteiT.ichardson l{b/oAttorney for Clearwatsr' Paper
STIPULATION A}ID SETTLEMENT- AW.E.15-05 & AW-G.Is-OI Page l8
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
26. The obligations of the Parties 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 court of competent jurisdiction.
27. This Stipulation may be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED this _ day of October,2015.
Avista Corporation
By:
David J. Meyer
Attorney for Avista Corporation
Clear-water Paper Corporation
By:
Peter Richardson
Attorney for Clearwater Paper
ldaho Conservation League
By:
Idaho Public Utilities Commission Staff
By:
Karl Klein
Brandon Karpen
Deputy Attorneys General
Benjamin J. Otto
Attorney for ICL
DeanJ. Miller
Attomey for Idaho Forest Group LLC
Snake River Alliance
By:
Kelsey Nunez
Attorney for Snake River Alliance
STIPULATION AND SETTLEMENT _ AVU-E-I5-05 & AV['J-G-I5-OI Page l8
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
26. The obligations of the Parties undsl 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 court of competent jurisdiction.
27. This Stipulation may be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED this day of October,2015.
Avista Corporation Idatro Public Utilities Commission Staff
By:By:
DavidJ. Meyer
Attorney for Avista Corporation
Clearwater Paper Corporation
By:
Peter Richardson
Attorney for Clearwater Paper
Karl Klein
Brandon Karpen
Deputy Attorneys General
Idaho Forest Group
Dean J. Miller
Attorney for Idaho Forest Group LLC
Snake RiverAlliance
By:
Kelsey Nunez
Attomey for Snake RiverAlliance
By:
STIPULATION AND SETTLEMENT _ AW.E-15.05 & AVU.G-Is.OI Page 18
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
26. The obligations of the Parties 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, ifany, by a court ofcompetentjurisdiction.
27. This Stipulation may be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED *,ir 15 day of october, 2015.
Avista Corporation
By:
David J. Meyer
Attorney for Avista Corporation
Clearwater Paper Corporation
By:
Peter Richardson
Attorney for Clearwater Paper
Idaho Conservation League
Idaho Public Utilities Commission Sta^ff
By:
Karl Klein
Brandon Karpen
Deputy Attorneys General
Forest Group
By:
Dean J. Miller
Attomey for Idaho Forest Group LLC
Idaho
By:
Beqiarnin J. Otto
Attorney for ICL
Kelsey N
STIPULATION AND SETTLEMENT - AVU-E.I5.05 & AVU.G.15-01 Page 18
or conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
26. The obligations of the Parties 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 court of competent.jurisdiction.
27. This Stipulation rnay be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED this _ day of October,2015.
ista Corporation Idaho Public Utilities Commission Staff
By:
Avr
By:
David J. Meyer
Attorney for Avista Corporation
Clearwater Paper Corporation
By:
Peter Richardson
Attorney for Clearwater Paper
Idaho Conservation League
Karl Klein
Brandon Karpen
Deputy Attorneys General
Idaho Forest Group
Dean J. Miller
Attorney for Idaho Forest Group LLC
Snake Rivcr Alliance
Kelsey Nunez
Attomey for Snake River Alliance
By:
By:By:
Benjamin J. Otto
Attorney for ICL
Community Action Partnership Association of Idaho
Brad Purdy
Attorney for CAPAI
STIPULATION AND SETTLEMENT - AVU-E-I5-05 & AVU-G.I5.OI Page 18
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Sumcost
Scenario: AVU-E-'I t05 Settlement Case
Load Factor Peak Oedit
Transmission By Demand 12 CP(b) (c) (d)
Description
Functional Cost Components at Cuneni Retum by Schedule
AVISTA UTILITIES ldaho Jurisdiction
Revenue to Cost by Functional Componeflt Summary Elecfic Utility
For Sle Twelve ltlonfis Ended Decemb€r 31, 2014
(e) (0 (s) (h) (D 0 (k)
Residential General Large Gen Extra Large Extra Large
System Service SeNice Seilice Gen Service Service CPTotel Sch 1 Sch 11-12 Sch21-n Sch 25 Sch 25P
01/01/16
(l) (m)
Pumping StEel &
Service Area Lighb
Sch 31-32 Sch 4149
2,009,519 388,872
364,384 42,983
2,077,164 2,459,555
826.933 598.589
1
2
3
4
5
6
7
I
q
10
Production
Transmission
Distribution
Common
Total Cunent Rate Revenue
Expressed as $/kwh
Production
Transmission
Disbibution
Common
Total Cunent Melded Rates
116,381,251 43,834,300 15,151,702 26,940,838 11,113,743 16,942,287
25,875,928 9,718,351 3,934,119 6,214,n1 2,249,812 3,3s1,999
61,3s1,755 29,831,665 10,779,769 14,076,269 1,699,1M 428,169
41.363.055 21.554.684 6.430.410 7.127.612 2.089.252 2.735.545
2M,972.0@ 104,939,000 36,296,000 54,359,000 17,1s2,000 23,458,000 5,278,000 3,490,000
$0.03787 $0.03820 $0.04174
$0.00842 $0.00847 $0.01084
$0.01996 $0.02600 $0.02970
s0.01346 $0.01879 $0.01771
$0.038s5 $0.03515 $0.03566 $0.03407 $0.02862
$0.00889 $0.00712 $0.00706 $0.m618 $0.00316
$0.02014 $0.00s37 $0.00090 $0.03521 $0.18101
$0.01020 $0.00661 $0.00576 $0.01402 $0.0440s
11 Pmducton
12 Transmission
13 Distribution
14 Common15 Total Uniform CunentCost
Expressed as MWh16 Production
17 Transmisson
18 Distribution
19 Common20 Total Cunent Ljniform Melded Rates
Rwenue to Colt Rdlo at Cursnt Ratee
$0.03750 $0.04030 $0.03898
$0.00831 $0.00986 $0.00909
$0.02035 $0.02934 $0.02564
$0.01356 $0.02014 $0.01620
$0.0373s $0.03468 $0.03241 $0.03364 $0.0A07
$0.00818 $0.00686 $0.00555 $0.00597 $0.00330
$0.018&r $0.00520 $0.00070 $0.03416 $0.18735
$0.00975 $0.00&19 $0.00505 $0.01378 $0.04507
Funclional Cost Components d unifom Curent Retum
$0.07972 $0.09146 $0.09999 $0.07779 $0.05425 $0.04938 $0.08948 $0.25684
115,229,071 46,239,37't 14,149,s6s 26,099,426 10,965,434 15,396,0'18 1,9U,232 395,025
25,531,066 11,315,196 3,299,985 5,714,435 2,170,174 2,634,191 352,205 44,880
62,527,167 33,660,930 9,307,333 13,023,320 1,642,916 331,779 2,015,160 2,545,729
41,684,695 23,112,21s 5,880,131 6,816,316 2,050,s18 2,400,469 812,634 612,411
244,972,N0 114,327,712 32,637,014 51,653,498 16,8A,043 n,762,457 5jU,232 3,598,045
$0.07972 $0,09964 $0.08991 $0.07392 50.05323 $0.04371 $0.0875s $0.2M80
1.02 0.971.131.021.051.110.921.00
30
3'1
22
23
24
25
1b
aa
33
34
35
36
JI
JO
39
40
41
0.971.021.13
1.12
1.02
1.01
1.110.921.00
t.t0
42
Fundional Cost Components al Proposod Rdum by Schedule
Pmduciion
Transmission
Disbibution
Common
Total Proposed Rate Revenue
116,879,049 44,076,123 15,198,811 27,043,470 11,161,961 16,990,473 2,017,744 390,467
26,179,972 9,878,907 3,963,927 6,275,248 2,27s,703 3,374,367 368,344 43,475
61,998,205 30,216,681 10,848,984 4,n4,700 1,717,451 431,172 2,097,329 2,481,887
41,614,774 21,711,289 6,456,278 7,165,582 2,101,885 2,745,987 931,583 ffi2,171
246,672,000 105,883,000 36,468,000 54,689,000 17,257,000 23,542,000 5,315,000 3,518,000
$0.01354 $0.01892 $0.0129 $0.01025 $0.00665 $0.00s78 $0.0'1410 $0.04432
$0.08027 $0.09228 $0.10046 $0.07826 $0.05458 $0.04956 $0.09011 $0.25890
115,740,980 46,444,790 14,212,425 26,215,374 11,014,149 15,464,41s 1,993,047 396,780
25,838,799 1'1,4s1,581 3,339,761 5,783,313 2,196,331 2,66s,941 356,451 45,421
63,160,604 33,987,985 9,399,691 13,168,414 1,661,391 336,043 2,0fi/74 2,570,307
41,931,6'17 23,245,244 5,914,647 6,859,212 2,063,251 2,415,291 817,619 616,354
246,672,000 115,129,600 32,866,523 52,026,313 16,935,122 20,881,690 5,203.891 3.628.86,1
Functional Cost Components d Unilorm Requested Retum
Common
Total Proposed Melded Rates
Pmduction
Transmission
Distribution
Common
TohlUniform Cost
&pressed as UkWh
Production
Transmission
Distribution
Common
Total Unilorm Melded Rates
Rryenuo to Coti R{lo d PDpoled R.ie!
cumnt Rryenue io PDpoaed Colt Raiio
Target Rwsue lnqcalc
$0.03766 $0.04048 $0,0391s
$0.00841 $0.00998 $0.00920
$0.02055 $0.02962 $0.02589
$0.01365 $0.02026 $0.01629
$0.03751 $0.03484
$0.00828 $0.00695
$0.01884 $0.00525
$0.00982 $0.00653
$0.0325s $0.03379 $0.02920
$0.00561 $0.00604 $0.00334
$0.00071 $0.03453 $0.18916
$0.00508 $0.01386 $0.04536
$0.08027 $0.10034 $0.09054 $0.07445 $0.05356 $0.04396 $0.08822 $0.26706
1.05
0.99 0.91 1.01 1.01 0.96
r0,190,000 (3,429,000) (2,333,000) (2r7,000) (2,s76,000)
Appendix B
Expressed as $/kWh
27
28
Production
Transmission
$0.03517 90.03421 10.02874
t0.00710 30.00624 t0.00320
43
1,700.000 (74,000)r39,000
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Line DBcription
AVISTA UTILITIES
Company Settlemeil Summary by Fundion with Margin Analysis
Case FortheYearEndedDecember3l, 2014
(b) (c) (O (e) (0
Naturd Gas Uiility
ldaho Jurisdidion
(e) (h) (i) (k)
Residential Largg Firm lntenupt Transport
SoNice SeMce SeMce SeMce
Sch 101 Scfi 111 Scfi 131 Sch 146
System
Total
Functlonal Coat Compononi. at Curront Ratc.'l Produclion2 Underground Storags3 Distribulion4 Common5 Tot l Curront Rlto Rov6nuo6 Exclude Cosi of Gas w / Revenue Exp.7 Total Margln R3vonue at Cun€nt Rata
Margin per Th6rm at Cunent Rat€88 Produclion9 Un(brground Storag€10 Distribution1'l Common'12 Total Cunent Margin Melded Rate per Thorm
'13 Produc'tion
14 Undorground Storage
15 Distribution
16 Common17 Total Uniform Cunent Cost18 Exclud6 Cost of Ga3 w / R€venus Exp.19 Total Uniform Cureni Margin
337,G1
1,746,119
24,249,ffi
9,&rc,181
235,918 97,',17'l
1,t35,497 561,698
19,367,000 4,614,0$
E.401.406 ',t.352.2'11
1,399 2,U25,600 43,32446,393 e ,2614.2U 72,ffi
36,173,000
0
29.139.84 e,425,127 07,59G
0
w,152
o
Func'tlonal Cort Componont3 .t Uniform Curront Retum
36,173,000 29,139,E24 6,624127 67,596 t&,452
$0.004i3 $0.00423 $0.00423 $0.00423 $0.00094$0.02137 $0.02038 $0.02448 $0.01695 S0.01600$0.29681 $0.34761 $0.20107 $0j4042 $0.08207$0.12044 $0.1s080 $0.0s893 $0.04299 $0.02672J0//,275 10.52303 00.28870 10.20459 10.12574
337.031 235,918 97,1711,689,279 1,231,419 416,37024,223,976 20,296,739 3,685,5619,922,715 8,625,255 1,2',t5,502 13,913 AqUs
36,173,000 30,389,33'1 5,414,605 64716 304,3|8
36,173,000 30,369,331 5,41'1,605 64716 304,348
1,399 2,5425,255 36,2354,149 197,526
20
21
22
23
24
Mtrgin per Th€rm at Uniform Cunent Retum
Production
Und6rground StoragE
Distdbution
Common
Tolal Cunent Uniform Margin Melded Rate perTh€rm
Uargln to Coat Rrtlo al Cunont Rat a
$0.00413
s0.02068
$0.29650
$0.12145
$0.00423
s0.02210
$0.38t30
$0.15/Br
$0.00423 $0.00423 $0.0008r
$0.018'14 $0.01590 $0.01338
s0.16061 $0.13363 $0.07295
s0.05297 $0.04211 $0.02513
25
10.4275
1.00
to.54!15 30.23595 30.19sE7 30.r124n
0.96 1.X2 1.U 1.',t2
Func{ional Co3t Compon6nt! at Propo.ed Rats
26 Produciion
27 Underground Storage
28 Distribution
29 Common
30 Total Propo36d Rato Rov3nue31 Exclude Cost of Gas w / RovenuE Exp.g2 Total Margln Revsnuo at Propossd Rabs
Common
Total Uni[orm Proposed Co6t
Exclude Cost of Gas w / R€v€nu€ Exp.
Total Uniform Proposod Margin
Margin per Therm at Uniform Proposed Retum
Produc-tion
Underground Storage
Distribution
Common
Total Propo3ed Uniform Margin Moldsd Rate per Therm
Mugln to Cost Rrtlo at Propolod Ratos
Currcnt M.llln to Propo.od Cost Rato
337,031
I,95't,059
m,1'14,616
10,270,295
235,9't8
1,306,768
2',t,o27,O55
8,801,083
97,',171
591,232
4,@2,732
1,399 2,542
6,200 46,859
50,288 2U,il11,379,992 14,709 74,511
38,673,000
0
g1,t?o,8u
0
6,871,127
0
72,598 358,45200
38,673,000 31,37O,8U 4,871,127 72,596 358,452
$0.12571 $0.06014 $0.04452 $o.o275236
37
38
39
40
41
42
43
44
rts
46
474
49
50
51
Total Propos6d Margin Melded Rate p€r Therm
Func'donrl Cost Compononts at Unlfom PEposod R3tum
Produclion
Und€rground StoEge
Distribution
Common
00.47335
337,031
1,903,251
26.093.052
3E,673,000
0
30.583{17
235,918
1,3E7,397
21.80E.556
c2,421,113
0
30.20942
97,',t7'l
1169,l 10
4,W.,507
1.265.1 t2
to.21973
1,399
5,920
48,472
14.474
00.13238
2,U2
4,425
213,517
70.838
38,673,000 32,121,113
$0.00413 $0.00423$0.02330 $0.02490$0.31938 $0.39144$0.12656 $0.16135
5,E53,900 70,265 327,7Ut
s0.00423
$0.02044
s0.17529
s0.05513
90.00423 $0.0009r
s0.01792 $0.01s08
$0.121671 $0.07866
$0.0438't s0.02616
t0.47335 s0.58192 1o.255r0 s,21?f,7
1.03
0.94
Appendix C
1.17
t0.12104
1.09
l.u
33
34
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s0.1 s797
0.07
1.13 0.95
Page 4 of 4
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AVISTA UTILITIES
IDAHO ELECTRIC, CASE NO. AVU.E.15.O5
PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE
Effective January 1, 2016
General
Rate
lnc/Oecrl
(e)
s0.00
(a)
Base Tariff Present Present
Scfi. Rate OtherAdi.(l) Billino Rate(b) (c) (d)
Proposed
Billing
Bcgc(0
$5.25
$10.00
$0.09834
$0.07364
$5.2s/kw
$0.06430
$0.05500
$350.00
$4.7s/kw
$0.20ftw
$0.05270
$0.04465
$12,500
$4.50/kva
$0.2o/kw
$687,360
$0.04280
$12,500
$4.50/kva
$2.00/kva
$0.2o/kw
$619,920
$8.00
00.09482
$0.0E100
Proposed
Base Tariff
Rate
(s)
$5.25
$r0.00
$0.09686
$0.07216
no charge
$5.2slkw
$0.06344
$0.05414
$3s0.00
$4.7slkw
$0.2olkw
s0.052sr
$0.04446
$r2,soo
$4.50/kva
$0.2olkw
$0.04272
$12,500
fi.50/kva
$2.00/kva
$0.20/kw
$8.00
$0.09365
$0.07983
Residential Service - Schedule I
Basic Charge
Energy Charge:
First 600 k\Ms
All over 600 k\Ms
General Services - Schedule 11
Basic Charge
Energy Charge:
First 3,650 kWhs
All over 3,650 k\Ms
Demand Charge:
20 kW or less
Over 20 kW
$5.25
$0.08146 $0.00101
$0.09096 $0.00101
$0.00078 $0.08325 $0.08224
$0.00087 $0.09284 90.09183
$10.00
$0.09634
$0.07178
no charge
$5.25lkw
$0.06297
$0.05373
$350.00
$4.75lkw
$0.2olkw
$0.0s212
$0.04414
$12,500
$4.50/kva
$0.2olkw
Present:
$0.04254
$12,500
$4.50/kva
$2.00/kva
$0.2olkw
Present:
$8.00
$0.09299
$0.07927
$0.00148
$0.00148
$0.00086
$0.00086
$0.00019
$0.00019
$683,420
$5.25
$0.08247
$0.09197
$10.00
$0.09782
$0.07326
no charge
$5.2slkw
$0.06383
$0.0s459
$350.00
$4.7slkw
$0.2olkw
$0.05231
$0.04433
$12,500
$4.50/kva
$0.2o/kw
$0.00
$0.00052
$0.00038
no charge
$0.00047
$0.00041
$0.00
$0.00039
$0.00032
$0.00018
$0.00
$0.00066
$0.000s6
Laroe General Service - Schedule 2l
Energy Charge:
First 250,000 k\Ms
All over 250,000 k\Ms
Demand Charge:
50 kW or less
Over 50 kW
Primary Voltage Discount
Extra Laroe General Service - Schedule 25
Energy Charge:
First 500,000 k\Ms
All over 500,000 k\Ms
Demand Charge:
3,000 kva or less
Over 3,000 kva
Primary Volt. Discount
Annual Minimum
Clearwater - Schedule 25P
Energy Charge:
all kWhs
Demand Charge:
3,000 kva or less
3,000 - 55,000 kva
Over 55,000 kva
Primary Volt. Discount
Annual Minimum
Pumoinq Service - Schedule 3l
Basic Charge
Energy Charge:
First 165 kwkwh
All additional k\Ms
$0.00008
$617,940
$0.00117
$0.00117
$0.04262
$12,500
$4.50/kva
$2.00/kva
$0.2o/kw
$8.00
$0.09416
$0.080,14
(1) lncludes all present rate adjustments: Schedule 59 - Residential & Farm Energy Rate Adjustment, Schedule 66 -
Temporary Power Cost Adjustment, Schedule 91 - Energy Efficiency Rider Adjustment, and Schedule 97 - Eamings
Test Rebate.
Stipulation and Settlement
Case No. AVU-E-15-05 and AVU-G-15-01
Avista
Page2 ol 4Appendix D
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AVISTA UTILITIES
IDAHO GAS, CASE NO. AVU.G.Is.OI
PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE
Effective January 1, 2016
Sch 197 -2013 Sch 197 -2014 Proposed
Present Base Present General Eaminga Teet Earnlngs Tost Proposod Base
Distribution Billing Present Rate & PGA Rebate Rebate Billing Dlstributlon
Tvoe of Service Rate Rate Adi.(1) Billino Rate lncrease Explration Credlt (2) Rate Rate(a) (b) (c) (d) (e) (0 (s) (h) (D
General Service - Schedule 101
Basic Charge $4.25 $4.25 $1.00
Usage Charge:
All therms $0.45372 $0.44741 $0.901'13 J0.02374
Laroe General Seruice - Schedule 1'll
Usage Charge:
First 200 therms
200 - 1,000 therms
1,000 - '10,000 therms
All over 10,000 therms
Minimum Gharge:
per month
per therm
$0.47s00 $o.4474'.1
$0.3't030 $0.44741
$0.23095 $0.4474',1
$0.17850 $0.44741
$95.00
$0.00000 $0.44741
$225.00
$0.1207s
$0.92241 s0.02875
$0.75771 $0.00924
$0.67836 $0.00688
$0.6259r $0.0053r
$95.00 $5.75
$o.44741
$0.01,|89
$0.01,189
$0.01,|89
$0.01't89
$0.01,t89
t0.0'1,089
$0.01,t89
($0.00268)
($0.00268)
($0.00268)
(t0.00268)
($0.00268)
($0.00268)
$5.25
$0.93708
$0.96337
$0.77916
30.69745
$0.6,lll,li!
$100.75
$0.45962
$5.25
$0.47746
$0.5037s
$0.3't954
$0.23783
$0.18381
$100.7s
$0.00000
$0.21972
$225.00
$0.'t2740
lnterruptable Set.ico - Schedule {32
Usage Charge:
All Therms $0.20459 $0.37021 $0.57480 30.01513
Transportation Service - Schedule 146
(so.oo268) $0.60214
$225.00
($0.00268) io.12472
Basic Charge
Usage Charge
All Therms
$225.O0
$0.12075
$0.00
t0.00665
(1) lncludes Schedule '150 - Purchased Gas CostAdjustment, Schedule 155 - Gas Rate Adjustment, and Schedule 197 - PGAi/DSM Rsbate
(2)The 2014 Eamings Test Rebate Credit will be effedive January 1, 2016 through December 31, 20'16
Stipulation and Settlement
Case No. AVU-E-15-05 and AVU-G-15-01
Avista
Page 4 of 4Appendix D
Schedule 197
Present Rebate Expirinq 1 2/31/201 5
Rebate of 2013 Earnings Test & DSM Defenals
GeneralService
Large GeneralService
lnterruptible Service
Pro Forma
Therms
55,714,011
22,947,786
0.01489
2014 Earnings
Pro Forma RebateTherms Reduction
55,714,011 $ (149,314)
22,947,796 $ (61,500)
330,3e6 $ (885)
2,707,661 $ (7,257)
81,699,954 $ (219,956)
Rate
Schedule
101
'1111112
't311132
Total
Uniform Cents Reduction
Proposed Rebate Effective l/1/16 - 1Z3ll15
Rebate of 2014 Earnings Test
GeneralService
Large General Service
lnterruptible Service
Transportation Service
Rate
Schedule
101
111t112
131t132
146
Total
2014 Earnings Test Balance
Uniform Cents Reduction
$
$
(219,212)
(0.00268)
Stipulation and Settlement
Case No. AVU-E-15-05 and AVU-G-15-01
Avista
Page 1 of 1
2013 Earnings
Rebate & DSM
Reduction$ 829,582$ 341,693$ 4,920
Appendix E