20150415Application.pdf

SEHM
An IDACORP Company
LISA D. NORDSTROM
Lead Counsel
[e-mail]
April 15,2015
VIA HAND DELIVERY
Jean D. Jewell, Secretary
ldaho Public Utilities Commission
472 West Washington Street
Boise, ldaho 83702
Re: Case No. IPC-E-15-14
2015-2016 Power Cost Adjustment - ldaho Power Company's Application
and Testimony
Dear Ms. Jewel!:
Enclosed for filing please find an original and seven (7) copies of ldaho Power
Company's Application in the above matter.
Also enclosed for filing are an original and eight (8) copies each of the Direct
Testimony of Scott Wright and Kelley K. Noe. One copy of each of the aforementioned
testimonies has been designated as the "Reporter's Copy." ln addition, a disk containing a
Word version of the testimonies is enclosed for the Reporter.
Lastly, four (4) copies each of ldaho Power Company's press release and customer
notice are also enclosed.
Very truly yours,
dr,, 1.1^,u,.*
Lisa D. Nordstrom
LDN:kkt
Enclosures
LISA D. NORDSTROM (lSB No. 5733)
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
I no rd strom@ idahopower.com
Attorney for ldaho Power Company
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO IMPLEMENT POWER
COST ADJUSTMENT (.PCA") P,q155
FOR ELECTRIC SERVICE FROM JUNE 1,
2015, THROUGH MAY 31,2016.
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. |PC-E-15-14
APPLICATION
ldaho Power Company ("ldaho Powed' or "Company"), in accordance with ldaho
Code SS 61-502 and 61-503 and RP 052, hereby respectfully makes application to the
ldaho Public Utilities Commission ("Commission") for an order approving an update to
Schedule 55 based on the quantification of the 2015-2016 Power Cost Adjustment to
become effective June 1, 2015, for the period between June 1, 2015, through May 31,
2016. The PCA rates listed on the proposed Schedule 55 include revenue sharing of
$7,999,145 in accordance with the terms of the settlement stipulation approved by
Order No.32424 in Case No. IPC-E-11-22. The Company has included its proposed
rates and charges for electric service in the state of ldaho as Attachment 1 to this
APPLICATION - 1
Application. !f approved, the 2015-2016 PCA will result in an overa!! revenue decrease
of approximately $10.1 million or a 0.91 percent decrease over current billed revenue.
In support of this Application, ldaho Power has prefiled testimony by two
Company witnesses to address various aspects of the 2015-2016 PCA filing.
Regulatory Analyst ll Scott Wright's testimony details the calculation of the proposed
2015-2016 PCA rates and explains the factors that impact this year's PCA
quantification. The testimony of Regulatory Analyst Il Kelley K. Noe describes ldaho
Poweds quantification of lhe 2014 revenue sharing benefits to be included in this yea/s
PCA.
I. BACKGROUND
1. ldaho Power is an Idaho corporation whose principal place of business is
1221West ldaho Street, Boise, ldaho 83702.
2. ldaho Power is a public utility supplying retail electric service in southem
ldaho and eastern Oregon. Idaho Power is subject to the jurisdiction of this
Commission in Idaho and to the jurisdiction of the Public Utility Commission of Oregon.
ldaho Power is also subject to the jurisdiction of the Federal Energy Regulatory
Commission.
3. On March 29, 1993, by Order No. 24806 issued in Case No. IPC-E-92-25,
the Commission approved the implementation of an annual power cost adjustment
procedure in order to provide consistency and stability to rates. The PCA is a cost
recovery mechanism that passes on both the benefits and the costs of supplying energy
to ldaho Power customers. Neither ldaho Power nor its shareholders receive any
financial return from the PCA.
APPLICATION - 2
4. On January 9, 2009, by Order No. 30715 issued in Case No. IPC-E-08-19,
the Commission approved certain changes to the PCA mechanism, including a 95
percenU5 percent sharing mechanism between customers and the Company. Order
No. 30715 also approved changes for the Load Growth Adjustment Rate ("LGAR'),
third-party transmission expense, the PCA forecast, and the power supply expense
distribution.
5. On January 13, 2010, the Commission issued Order No. 30978 approving
the settlement stipulation filed in lieu of a general rate case in Case No. IPC-E-09-30.
Through this stipulation, a revenue sharing mechanism was established to allow the
Company to accelerate the amortization of Accumulated Deferred lnvestment Tax
Credits ("ADITC") if the Company's actua! ldaho jurisdictional year-end Return on Equity
("ROE') fell below 9.5 percent in any fiscal year from 2009 through 2011. This
mechanism also included a provision for revenue sharing if the Company's actua! ldaho
jurisdictional year-end ROE exceeded 10.5 percent in any year over the same three-
year period. Per the terms of the stipulation, 50 percent of the ldaho jurisdictional year-
end ROE in excess of 10.5 percent was to be shared with customers in the form of a
rate reduction.
6. On March 15, 2011, the Commission issued Order No. 32206 adopting a
revised LGAR methodology and changing the name of the methodology to the Load
Change Adjustment Rate (LCAR).
7. On December 27, 201'1, the Commission issued Order No. 32424
approving the settlement stipulation filed on December 12,2011, extending the revenue
APPLICATION - 3
sharing mechanism through 2014,1 and modifying portions of the previous accounting
order. More specifically, Order No.32424 approved modifications to the sharing portion
of the mechanism, which allows for greater customer benefits. First, for actual year-end
ldaho jurisdictional earnings greater than 10 percent ROE up to and including 10.5
percent in any year from 2012 through 2014, the earnings will be shared equally
between ldaho customers and the Company. The customer revenue sharing benefit will
be in the form of a reduction to rates at the same time as the PCA becomes effective.
This modification provides customers an additional25 basis points of sharing potential.
Second, ldaho earnings above a 10.5 percent ROE will also be shared, with customers
receiving 75 percent of the earnings applied as an offset to the Company's pension
balancing account.
ll. 2015-2016 PCA CALCULATTON
8. The PCA is a rate mechanism that quantifies and tracks annual
differences between actual Net Power Supply Expense ('NPSE') and the normalized or
"base level" of NPSE recovered in the Company's base rates for recovery or credit
through an annual rate. change on June 1. The PCA is also the rate mechanism used
by the Company to provide direct revenue sharing benefits resulting from the revenue
sharing mechanism approved by Order No.32424.
9. The PCA mechanism utilizes a 12-month test period of April through
March ("PCA Yea/') and is comprised of a forecast component and a PCA True-Up
component. The PCA forecast component is based on the Company's March Operating
Plan and represents the difference between the NPSE forecast from the March
tOn October 9, 2O14, the Commission approved extension of the revenue sharing mechanism
with modifications beyond 2014 in Order No. 33149 issued in Case No. IPC-E-14-14. Changes to the
mechanism approved in Order No. 33149 will take effect with fiscal year-end 2015 financial results.
APPLICATION.4
Operating Plan and the base level NPSE recovered in the Company's base rates. The
PCA True-Up includes a backward looking tracking of differences between the prior
yea/s forecast and actual NPSE incurred by the Company during the prior PCA year.
The PCA True-Up contains a second component that tracks the collection of the prior
yeads true-up amount, referred to as the "True-Up of the True-Up."
10. With the exception of Public Utility Regulatory Policies Act of 1978
('PURPA") expenses and demand response incentive costs, the PCA allows the
Company to pass through to customers g5 percent of the annual differences in actual
NPSE as compared to the base level NPSE, whether positive or negative.
11. The testimony and exhibits of Mr. Wright describe and compute the
standard PCA rate to be effective June 1, 2015, through May 31 , 2016. The system-
level forecast of NPSE for the 2015-2016 PCA Year is for $348,384,126, which is
$42,699,257 higher than the currently approved base level NPSE of $305,684,869 and
$18,357,870 higher than last yea/s forecast amount of $330,026,256. The 2015-2016
PCA forecast component that is expected to be collected from ldaho customers is
$39,140,610. lncreases in PURPA costs account for approximately 76 percent or $13.9
million of the year-over-year increase in this yea/s PCA forecast.
12. The True-Up deferral balance at the end of March 2015, with interest
applied, was $34,515,981. This charge to customers was largely driven by lower than
forecast market energy prices resulting in lower surplus sales volumes. As a result, the
Company experienced lower than expected surplus sales revenue, which serves to
offset power supply expense.
13. ln the True-Up of the True-Up, the Company under collected last yea/s
PCA True-Up Balance by $1,484,515. Even though the 2014-2015 combined PCA
APPLICATION - 5
True-Up was a positive value, it represents a decrease of approximately $41.2 million
as compared to the 2013-2014 combined PCA True-Up balance because the forecast
for the 2014-2015 PCA was more accurate than the previous yea/s forecast for the
2013-2014 PCA.
14. The Company's PCA rate for the 2015-2016 PCA year is detailed in
Wright Exhibit No. 2, column E. The uniform PCA rate is comprised of (1) the 0.2815
cents per kilowatt-hour ('kwh") adjustment for the 2015-2016 projected power cost of
serving firm loads, under the current PCA methodology and 95 percent sharing, (2) the
0.2483 cents per kWh for the 2014-2015 True-Up portion of the PCA, and (3) the
0.0107 cents per kWh for the True-Up of the True-Up. The sum of these three
components results in a 0.5405 cents per kWh charge for all rate classes.
15. The Company proposes the continued application of a PCA credit related
to the Demand-Side Management ("DSM") Rider in the amount of $3,970,036 to
maintain the revenue neutrality associated with the June 2014 update to the normalized
level of NPSE included in base rates approved by Order No. 33000. This adjustment
results in a uniform rate credit for all customer classes of (0.0286) cents per kWh.
!II. REVENUE SHARING BENEFITS
16. ldaho Powe/s actual ldaho jurisdictional year-end ROE resulted in no
accelerated amortization of ADITC or revenue sharing in 2009 and 2010. ln 2011,
2012, and 2013, the Company has shared with customers a total of $93.3 million either
as a direct rate offset in the PCA or as an offset to amounts that would otherwise be
collected in rates.
17. As described in greater detail in the direct testimony and exhibits of Ms.
Noe, the Company's 2014 Idaho jurisdictional year-end ROE was 11.19 percent. ln
APPLICATION - 6
accordance with the terms of the modified revenue sharing mechanism approved by
Order No. 32424. customers will receive a total benefit of $24,692,279-a rate credit of
$7,999,145 and a $16,693,134 offset to the Company's pension balancing account.
18. With the exception of the special contracts for Micron Technology, lnc.,
the U.S. Department of Energy, and the J.R. Simplot Company - Pocatello,2 ldaho
Power proposes to include the class-allocated revenue sharing benefits as an offset to
the 2015-2016 PCA rates effective June 1, 2015, through May 31 , 2016. Consistent
with the methodology used to share 2011,2012, and 2013 revenues, the Company
proposes to provide the special contract customers a flat dollar-per-month credit in
twelve equal portions to serve as an offset to monthly invoices billed for June 2015
through May 2016.
IV. PROPOSED 2015.2016 PCA RATE DECREASE
19. The 2015-2016 total PCA amount (including an $8.0 million revenue
sharing rate credit and a $4.0 million DSM Rider adjustment) as measured from the
currently approved base level NPSE is $63.1 million. This represents a decrease in
total billed revenue of $10.1 million, a reduction of 0.91 percent.
20. Attachment 1 to this Application is a copy of ldaho Poweds proposed new
IPUC No.29, Tariff No. 101, in both final and legislative formats, which contains the
tariff sheets specifying the proposed rates for providing retail electric service to its
customers in the state of ldaho.
21. Attachment 2 to this Application contains a summary of revenue impact
showing the effect to each customer class and special contract customer of applying the
2Although ldaho Power has requested Commission approval of a special contract for Simplot's
Caldwell facility in Case No. IPC-E-15-13 to become effective the month its energy consumption exceeds
20 megawatts, Simplot's Caldwell facility will receive 2014 revenue sharing benefits as a Schedule 19
customer.
APPLICATION - 7
Company's proposed rates that collect $10.1 million less during the 2015-2016 PCA
Year than the PCA rates currently in effect.
V. MODIFIED PROCEDURE
22. ldaho Power believes that a technical hearing is not necessary to consider
the issues presented herein and respectfully requests that this Application be processed
under Modified Procedure; i.e., by written submissions rather than by hearing. RP 201,
ef seg. lf, however, the Commission determines that a technical hearing is required, the
Company stands ready to present its testimony and support the Application in such
hearing.
VI. COMMUNICATIONS AND SERVICE OF PLEADINGS
23. As it committed to do in last year's PCA proceeding, Case No. IPC-E-14-
05, ldaho Power worked with the Commission Staff on the timing and content of PCA
customer notifications prior to filing this Application. These efforts also resulted in the
enhancement of PCA information available on ldaho Power's website accessible by
both desktop and mobile users.
24. In conformance with RP 125, this Application will be brought to the
attention of ldaho Poweds customers by means of a press release to media in the
Company's service area and a customer notice distributed in customers' bills, both of
which accompany this filing. The customer notice will be distributed over the course of
the Company's billing cycle, with the last notice being sent on May 21,2015, despite the
provision of RP 125.02 that allows for timely communication of an annual cost
adjustment after the rate decrease is approved by the Commission. Idaho Power will
also keep its Application, testimony, and exhibits open for public inspection at its offices
throughout the state of ldaho. ldaho Power asserts that this notice procedure satisfies
APPLICATION - 8
the Rules of Procedure of this Commission; however, the Company will, in
alternative, bring the Application to the attention of its affected customers through
other means directed by this Commission.
25. Communications and service of pleadings with reference to
Application should be sent to the following:
the
any
this
Lisa D. Nordstrom
Regulatory Dockets
ldaho Power Company
P.O. Box 70
Boise, ldaho 83701
Timothy E. Tatum
Gregory W. Said
ldaho Power Company
P.O. Box 70
Boise, ldaho 83707
[e-mail] [e-mail]
[e-mail] [e-mail]
VII. REQUEST FOR RELIEF
26. ldaho Power respectfully requests that the Commission issue an order
approving an update to Schedule 55 based on the quantification of the 2015-2016 PCA,
resulting in an overall decrease to current billed revenue of approximately $10.1 million
to become effective June 1,2015, as detailed in Attachment 2.
DATED at Boise, ldaho, this 1sth day of April 2015.
Attorney for ldaho Power Company
APPLICATION - 9
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-15-14
IDAHO POWER COMPANY
ATTACHMENT 1
PROPOSED TARIFF
(final and legislative formats)
FINAL FORMAT
ldaho Power Company Ninth Revised Sheet No. 55-1
Cancels
|.P.U.C. No. 29. Tariff No. 101 Eiohth Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all ldaho retail Customers served
under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for
purposes of this schedule.
BASE POWER COST
The Base Power Cost of the Company's rates is computed by dividing the sum of the
Company's power cost components by firm kWh sales. The power cost components are segmented
into three categories: Category 1, Category 2 and Category 3. Category 1 power costs include the sum
of fuel expense and purchased power expense (excluding purchases from cogeneration and small
power producers), less the sum of off-system surplus sales revenue and revenue from market-based
special contract pricing. Category 2 power costs include purchased power expense from cogeneration
and small power producers. Category 3 power costs include demand response incentive payments.
The Base Power Cost is 21052 cents per kWh, which is comprised of Category 1 power costs of
1.1040 cents per kWh, Category 2 power costs of 0.9203 cents per kWh and Category 3 power costs of
0.0809 cents per kWh.
PROJECTED POWER COST
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the
Category 1, Category 2 and Category 3 power cost components for the forecasted time period
beginning April 1 each year and ending the following March 31. The Prolected Power Cost is 2.3977
cents per kWh, which is comprised of Category 1 power costs of 1.3228 cents per kWh, Category 2
power costs of 1.0179 cents per kWh and Category 3 power costs of 0.0570 cents per kWh.
TRUE-UP AND TRUE-UP OF THE TRUE-UP
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up of the True-up is the difference between the previous
year's approved True-Up revenues and actual revenues collected. The total True-up is 0.2590 cents
per kWh.
EARNINGS SHARING
Order Nos. 30978 and 32424 directed the Company to share a portion of its earnings above a
certain threshold with customers through the annual Power Cost Adjustment. The following rate
schedules will receive a rate reduction benefit associated with the Company's 2014 earnings in the
form of a cents per kWh rate. The Company's Special Contract customers will receive rate reduction
benefits associated with the Company's 2014 earnings in the form of a monthly credit for each month of
the rate effective period.
Schedule
1
3
5
7
9S
9P
Description
Residential Service
Master Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Small General Service
Large General Service - Secondary
Large General Service - Primary
d per kWh
(0.0713)
(0.067e)
(0.0684)
(0.08e7)
(0.0s34)
(0.0463)
!DAHO
lssued per Order No.
Effective - June 1, 2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fourth Revised Sheet No. 55-2
Cancels
|.P.U.C. No. 29. Tariff No. 101 Third Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (Continued)
9T
15
19S
19P
197
24
40
41
42
Large General Service - Transmission (0.0484)
Dusk to Dawn Lighting (0.1560)
Large Power Service - Secondary (0.0463)
Large Power Service - Primary (0.0410)
Large Power Service - Transmission (0.0394)
Agricultural lrrigation Service (0.0578)
Unmetered General Service (0.0639)
Street Lighting (0.1022)
Traffic Control Lighting (0.0452)
Monthlv Credit
26
29
30
Schedule
1
3
5
7
9S
9P
9T
15
195
19P
197
24
40
41
42
Micron
Simplot
DOE
Micron
Simplot
DOE
($14,629.27)
($ 5,656.11)
($ 6,528.59)
(0.0286)
(0.0286)
(0.0286)
TRANSFER OF DEMAND SIDE MANAGEMENT ("DSM") RIDER FUNDS
The following rate schedules will receive a rate reduction benefit associated with the transfer of
DSM Rider funds in the form of a cents per kWh.
Description I per kWh
Residential Service (0.0286)
Master Metered Mobile Home Park (0.0286)
Residential- Time-of-Day Pilot Plan (0.0286)
Small General Service (0.0286)
Large General Service - Secondary (0.0286)
Large General Service - Primary (0.0286)
Large General Service - Transmission (0.0286)
Dusk to Dawn Lighting (0.0286)
Large Power Service - Secondary (0.0286)
Large Power Service - Primary (0.0286)
Large Power Service - Transmission (0.0286)
Agricultural lrrigation Service (0.0286)
Unmetered General Service (0.0286)
Street Lighting (0.0286)
Traffic Control Lighting (0.0286)
26
29
30
IDAHO
lssued per Order No.
Effective - June 1, 2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, Idaho
ldaho Power Company Third Revised Sheet No. 55-3
Cancels
|.P.U.C. No. 29. Tariff No. 101 Second Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment is the sum of: 1) 95 percent of the difference between the Projected
Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the difference
between the Projected PowerCosts in Category 2and the Base PowerCosts in Category2; 3) 100
percent of the difference between the Projected Power Costs in Category 3 and the Base Power Costs
in Category 3; 4) the True-ups; 5) Earnings Sharing; and 6) the transfer of DSM Rider funds.
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules
and Special Contracts are shown below. The rates below do not include the monthly Earnings Sharing
credits for each of the Special Contract customers (Schedules 26, 29, and 30). The monthly Power
Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated
usage times the cents per kWh rates shown below.
Schedule
1
3
5
7
9S
9P
9T
15
19S
19P
197
24
40
41
42
Description d per kWh
Residential Service 0.4406
Mastered Metered Mobile Home Park 0.4440
Residential- Time-of-Day Pilot Plan 0.4436
Small General Service 0.4222
Large General Service - Secondary 0.4585
Large General Service - Primary 0.4656
Large General Service - Transmission 0.4636
Dusk to Dawn Lighting 0.3559
Large Power Service - Secondary 0.4656
Large Power Service - Primary 0.4709
Large Power Service - Transmission 0.4725
Agricultural lrrigation Service 0.4541
Unmetered General Service 0.4480
Street Lighting 0.4097
Traffic Control Lighting 0.4667
26
29
30
Micron
Simplot
DOE
0.51 19
0.5119
0.5119
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 ,2016.
IDAHO
lssued per Order No.
Effective - June 1, 2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
LEGISLATIVE FORMAT
ldaho Power Company EighthNinth Revised Sheet No. 55-1
Cancels
|.P.U.C. No. 29. Tariff No. lOlSeventhEiqhth Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPL!CABILITY
This schedule is applicable to the electric energy delivered to all ldaho retail Customers served
under the Company's schedules and Special Contracts. These loads are referred to as 'Tirm" load for
purposes of this schedule.
BASE POWER COST
The Base Power Cost of the Company's rates is computed by dividing the sum of the
Company's power cost components by firm kWh sales. The power cost components are segmented
into three categories: Category 1, Category 2 and Category 3. Category 1 power costs include the sum
of fuel expense and purchased power expense (excluding purchases from cogeneration and small
power producers), less the sum of off-system surplus sales revenue and revenue from market-based
special contract pricing. Category 2 power costs include purchased power expense from cogeneration
and small power producers. Category 3 power costs include demand response incentive payments.
The Base Power Cost is 2JW2.1052 cents per kWh, which is comprised of Category 1 power costs of
1-13+71.1040 cents per kWh, Category 2 power costs of 0€4260.9203 cents per kWh and Category 3
power costs of 0€8390.0809 cents per kWh.
PROJECTED POWER COST
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the
Category 1, Category 2 and Category 3 power cost components for the forecasted time period
beginning April 1 each year and ending the following March 31. The Projected Power Cost isZ#7rucents per kWh, which is comprised of Category 1 power costs of {'3zsro.-1.3228 cents per
kWh, Category 2 power costs of 9€.4rc15179. cents per kWh and Category 3 power costs of
0-06120.0570 cents per kWh.
TRUE.UP AND TRUE-UP OF THE TRUE.UP
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up of the True-up is the difference between the previous
year's approved True-Up revenues and actual revenues collected. The total True-up is 05696Q2590
cents per kWh.
EARNINGS SHARING
Order Nos. 30978 and 32424 directed the Company to share a portion of its earnings above a
certain threshold with customers through the annual Power Cost Adjustment. The following rate
schedules will receive a rate reduction benefit associated with the Company's 20134 earnings in the
form of a cents per kWh rate. The Company's Special Contract customers will receive rate reduction
benefits associated with the Company's 2014 earnings in the form of a monthly credit for each month
of the rate effective period.
Schedule
1
3
5
7
9S
9P
Description
Residential Service
Master Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Small General Service
Large General Service - Secondary
Large General Service - Primary
d per kWh
(0.06e5713)
(0.0ffi67e)
(0.06€[]684)
(0.086s8e7)
(0.0++s534)
(0.0451@)
IDAHO
lssued per Order No. 33049
Effective - June 1,20145
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company +hidFogth Revised Sheet No. 55-2
Cancels
!.P.U.C. No. 29. Tariff No. l0l SeeendThird Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHAR! NG (Continued)
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
Agricultural lrrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Monthlv Credit
Micron
Simplot
DOE
26
29
30
9T
15
19S
19P
197
24
40
41
42
Schedule
1
3
5
7
9S
9P
9T
15
195
19P
197
24
40
41
42
I per kWh
(017580286)
(0.{€830286)
(0 {€s20286)
(0.2{260286)
(0.{€850286)
(01?+30286)
(0 12750286)
(0 34920286)
(0.{+azozaol
(0.#€50286)
(0 +1040286)
1s 14+S0286)
(0.{€0+0286)
(0.234+0286)
(0.1++80286)
(0.1€340286)
(0.{€000286)
(0.lor+ozao1
(0.0466484)
(0.151+1560)
(0.044@)
(0.039e410)
(0.03853%)
(0.05s578)
(0.0m63e)
(0.w+ts221
(0.043e4s2)
($13W714.629.27)
($ 5Js9J+5.656.1_1)
($ ffi.528.59)
TRANSFER OF DEMAND SIDE MANAGEMENT ('DSM') RIDER FUNDS
The following rate schedules will receive a rate reduction benefit associated with the transfer of
DSM Rider funds in the form of a cents per kWh.
26
29
30
Description
Residential Service
Master Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Small General Service
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
Agricultural !rrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
IDAHO
lssued per Order No. 33949
Effective - June 1,20145
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Seeenalhtfl Revised Sheet No. 55-3
Cancels
l.P.U.C. No. 29. Tariff No. 101 FirstSecond Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment is the sum of: 1) 95 percent of the difference between the Projected
Power Costs in Category 1 and the Base Power Costs in Category 1;2) 100 percent of the difference
between the Projected Power Costs in Category 2and the Base Power Costs in Category 2; 3) 100
percent of the difference between the Projected Power Costs in Category 3 and the Base Power Costs
in Category 3; 4) the True-ups; 5) Earnings Sharing; and 6) the transfer of DSM Rider funds.
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules
and Special Contracts are shown below. The rates below do not include the monthly Earnings Sharing
credits for each of the Special Contract customers (Schedules 26, 29, and 30). The monthly Power
Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated
usage times the cents per kWh rates shown below.
Schedule
1
3
5
7
9S
9P
9T
15
195
19P
197
24
40
41
42
d per kWh0.4w
0.M34440
0.49504436
0.$$4222
0.54024585
0.561{@0.556@
0.22e635590.sre
0.5771^7090.*1w250.w
0.598444800.3eery
0.56484667
Description
Residential Service
Mastered Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Small General Service
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
Agricultural I rrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
26
29
30
0.6274i5119
o.ffis119
0.62945119
EXPIMTION
The Power Cost Adjustment included on this schedule will expire May 31, 20150.
IDAHO
lssued per Order No. 33049
Effective - June 1,20145
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-15-14
IDAHO POWER COMPANY
ATTACHMENT 2
REVENUE IMPACT SUMMARY
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