20160415Application.pdf

RECEIVED
2016 PR I 5 PM y: 34
An IDACORP company
LISA D. NORDSTROM
Lead Counsel
[e-mail]
April 15, 2016
VIA HAND DELIVERY
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
Boise, Idaho 83702
Re: Case No. IPC-E-16-08
2016-2017 Power Cost Adjustment - Idaho Power Company's Application
and Testimony
Dear Ms. Jewell:
Enclosed for filing in the above matter please find an original and seven (7) copies
of Idaho Power Company's Application.
Also enclosed for filing are an original and eight (8) copies of the Direct Testimony of
Matthew T. Larkin. One copy of the aforementioned testimony has been designated as the
"Reporter's Copy." In addition, a disk containing a Word version of Mr. Larkin's testimony
is enclosed for the Reporter.
Lastly, four (4) copies each of Idaho Power Company's press release and customer
notice are also enclosed.
Very truly yours,
��!!.� Lisa D. Nordstrom
LDN:csb
Enclosures
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
LISA D. NORDSTROM (ISB No. 5733)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70 Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
Attorney for Idaho Power Company
RECEIVE D
2016 :'. · R I 5 P 4: 3 5
I�''. i - "" 'f.:,LIC
·: f n.n Ii � :01\\HISSION
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-16-08
AUTHORITY TO IMPLEMENT POWER ) COST ADJUSTMENT ("PCA") RA TES ) APPLICATION
FOR ELECTRIC SERVICE FROM JUNE )
1, 2016, THROUGH MAY 31 , 2017. )
���������������-)
Idaho Power Company ("Idaho Power" or "Company"), in accordance with Idaho
Code§§ 61-502 and 61-503 and RP 052, hereby respectfully makes application to the
Idaho Public Utilities Commission ("Commission") for an order approving an update to
Schedule 55 based on the quantification of the 2016-2017 Power Cost Adjustment
("PCA") to become effective June 1, 2016, for the period between June 1, 2016, through
May 31, 2017. The PCA rates listed on the proposed Schedule 55 include revenue
sharing of $3, 159,478 in accordance with the terms of the settlement stipulation
approved by Order No. 33149 in Case No. IPC-E-14-14. The Company has included its
APPLICATION - 1
proposed rates and charges for electric service in the state of Idaho as Attachment 1 to
this Application. If approved, the 2016-2017 PCA will result in an overall revenue
increase of approximately $17.3 million, or a 1.57 percent increase over current billed
revenue.
In support of this Application, Idaho Power has filed the Direct Testimony of
Revenue Requirement Manager Matthew T. Larkin, which details the calculation of the
proposed 2016-2017 PCA rates and explains the factors that impact this year's PCA
quantification.
I. BACKGROUND
1 . Idaho Power is an Idaho corporation whose principal place of business is
1221 West Idaho Street, Boise, Idaho 83702.
2. Idaho Power is a public utility supplying retail electric service in southern
Idaho 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.
Idaho 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 costs of supplying energy to
Idaho Power customers. Neither Idaho 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
percent/5 percent sharing mechanism between customers and the Company. Order
No. 30715 also approved changes to 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 in Case
No. IPC-E-09-30 approving the settlement stipulation filed in lieu of a general rate case.
Through this stipulation, a revenue sharing mechanism was established to allow the
Company to accelerate the amortization of Accumulated Deferred Investment Tax
Credits ("ADITC") if the Company's actual Idaho 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 actual Idaho
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 Idaho 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 in Case No.
GNR-E-10-03 adopting a revised LGAR methodology and changing the name of the
methodology to the Load Change Adjustment Rate ("LCAR").
7. On December 27, 2011, the Commission issued Order No. 32424 in Case
No. IPC-E-11-22 approving the settlement stipulation filed on December 12, 2011 ,
extending the revenue sharing mechanism through 2014 and modifying portions of the
APPLICATION - 3
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 Idaho 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 Idaho 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
I becomes effective. This modification provides customers an additional 25 basis points
of sharing potential. Second, Idaho 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.
8. On October 9, 2014, the Commission issued Order No. 33149 in Case No.
IPC-E-14-14 approving the settlement stipulation filed on September 3, 2014, extending
the revenue sharing mechanism through 2019 and modifying portions of the previous
accounting order. More specifically, Order No. 33149 approved modifications to the
sharing mechanism to reflect adjustments to the various sharing thresholds, as well as
the method by which shared amounts would be provided to customers. First, for actual
year-end Idaho jurisdictional earnings greater than 10 percent ROE, up to and including
10.5 percent in any year from 2015 through 2019, the earnings will be shared between
customers and the Company on a 75 percent and 25 percent basis, respectively. The
customer revenue sharing benefit will be in the form of a reduction to rates at the same
time as the PCA becomes effective. Second, Idaho earnings above a 10 .5 percent
ROE will also be shared, with customers receiving 50 percent of the earnings in the
form of a reduction to rates at the same time as the PCA becomes effective, as well as
APPLICATION - 4
25 percent of the earnings applied as an offset to the Company's pension balancing
account, with the Company retaining the remaining 25 percent.
9. On May 28, 2015, the Commission issued Order No. 33307 in Case No.
IPC-E-15-15 converting the LCAR to a Sales Based Adjustment ("SBA") rate, as well as
modifying the PCA deferral balance's monthly interest calculation. Per Order No.
33307, the SBA rate will be calculated in the same manner as the LCAR, with the only
modification being the replacement of the load-based megawatt-hour ("MWh")
denominator with the corresponding sales-based MWh denominator. Second, the
Order requires the Company to calculate monthly interest on the deferral balance by
assigning annual base Net Power Supply Expense ("NPSE") to each month according
to expected base rate revenue collection as set in the Company's last general rate
case, Case No. IPC-E-11-08.
II. 2016-2017 PCA CALCULATION
10. The PCA is a rate mechanism that quantifies and tracks annual
differences between actual 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 in Order No. 33149.
1 1 . The PCA mechanism utilizes a 12-month test period of April through
March ("PCA Year") and is comprised of a forecast component and a true-up
component ("True-Up"). The PCA forecast component is based on the Company's
March Operating Plan and represents the difference between the NPSE forecast from
APPLICATION - 5
the March Operating Plan and the base level NPSE recovered in the Company's base
rates. The True-Up includes a backward looking tracking of differences between the
prior year'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 year's True-Up amount, referred to as the "True-Up of the True-Up."
12. 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 95 percent of the annual differences in actual
NPSE as compared to the base level NPSE, whether positive or negative.
13. The testimony and exhibits of Mr. Larkin describe and compute the
standard PCA rate to be effective June 1 , 2016, through May 31, 2017. The system­
level forecast of NPSE for the 2016-2017 PCA Year is $357,547,740, which is
$51 ,862,871 higher than the currently approved base level NPSE of $305,684,869 and
$9, 163,614 higher than last year's forecast amount of $348,384, 126. The primary factor
contributing to this year's PCA forecast increase is costs associated with power
purchase agreements under PURPA. PURPA costs have increased by approximately
$10 million over last year primarily because of the addition of new solar contracts. The
2016-2017 PCA forecast component that is expected to be collected from Idaho
customers is $47,764,680.
14. The True-Up deferral balance at the end of March 2016, with interest
applied, was $43,661, 193. This charge to customers was largely driven by lower than
forecast hydro generation, as well as lower than forecast market energy prices, which
APPLICATION - 6
result in lower surplus sales volumes. As a result, the Company experienced lower than
expected surplus sales revenue, which serves to offset power supply expense.
15. In the True-Up of the True-Up, the Company over collected last year's
PCA True-Up balance by $5,073, 137. The 2015-2016 combined PCA True-Up is an
increase of $4,058,357 over the 2014-2015 combined PCA True-Up.
16. The Company's PCA rate for the 2016-2017 PCA Year is detailed in
Exhibit No. 2, column E, attached to Mr. Larkin's testimony. The uniform PCA rate is
comprised of (1) the 0.3422 cents per kilowatt-hour ("kWh") adjustment for the 2016-
2017 projected power cost of serving firm loads, under the current PCA methodology
and 95 percent sharing, (2) the 0.3129 cents per kWh for the 2015-2016 True-Up
portion of the PCA, and (3) the negative 0.0364 cents-per-kWh for the True-Up of the
True-Up. The sum of these three components results in a 0.6187 cents-per-kWh
charge for all rate classes.
17. The Company proposes the continued application of a PCA credit related
to the Demand-Side Management Rider ("DSM Rider") in the amount of $3,970,036 in
order to maintain the revenue neutrality associated with the June 2014 update to the
normalized level of NPSE included in base rates approved in Order No. 33000. This
adjustment results in a uniform rate credit for all customer classes of (0.0284) cents per
kWh.
Ill. REVENUE SHARING BENEFITS
18. The Company's earnings in each year from 2011 through 2014 resulted in
revenue sharing with Idaho customers totaling $118 million, either as a direct rate offset
APPLICATION - 7
in the PCA or as an offset to amounts that would have otherwise been collected in
rates.
19. As described in greater detail in the direct testimony and exhibits of Mr.
Larkin, the Company's 2015 Idaho jurisdictional year-end ROE was 10 .13 percent. In
accordance with the terms of the modified revenue sharing mechanism approved by
Order No. 33149, Idaho customers will receive a total benefit of $3, 159,478 as a direct
reduction to PCA rates effective June 1 , 2016.
20. With the exception of the special contracts for Micron Technology, Inc.,
the U.S. Department of Energy, and the J.R. Simplot Company - Pocatello,1 Idaho
Power proposes to include the class-allocated revenue sharing benefits as an offset to
the 2016-2017 PCA rates effective June 1 , 2016, through May 31 , 2017. Consistent
with the methodology used to share 2011, 2012, 2013, and 2014 revenues, the
Company proposes to provide the special contract customers a flat dollar-per-month
credit in 12 equal portions to serve as an offset to monthly invoices billed for June 2016
through May 2017.
IV. PROPOSED 2016-2017 PCA RATE INCREASE
21. The 2016-2017 total PCA amount (including a $3.2 million revenue
sharing rate credit and a $4.0 million DSM Rider adjustment), as measured from the
currently approved base level NPSE, is $79.2 million. This represents an increase in
total billed revenue of $17 .3 million, an increase of 1.57 percent.
1 Although the Commission approved a special contract for J.R. Simplot Company's Caldwell
facility in Case No. I PC-E-15-13 to become effective the month its energy consumption exceeds 20 megawatts, the facility's consumption has not exceeded this threshold to date. Consequently, J.R. Simplot Company's Caldwell facility will receive 2015 revenue sharing benefits as a Schedule 19 customer.
APPLICATION - 8
22. Attachment 1 to this Application is a copy of Idaho Power's proposed new
IPUC No. 29, Tariff No. 101, in both clean and legislative formats, which contains the
tariff sheets specifying the proposed rates for providing retail electric service to its
customers in the state of Idaho.
23. 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
Company's proposed rates that collect $17.3 million more from June 2016 through May
2017 than the PCA rates currently in effect.
V. MODIFIED PROCEDURE
24. Idaho 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,
et seq. If, 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
25. In conformance with RP 125, this Application will be brought to the
attention of Idaho Power's 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 20, 2016. The
Company has also prominently displayed its intent to file the PCA on its website since
March 15, 2016. Upon filing, this web graphic will link directly to the PCA press release
APPLICATION - 9
and bill insert. Idaho Power will also keep its Application, testimony, and exhibits open
for public inspection at its offices throughout the state of Idaho. Idaho Power asserts
that this notice procedure satisfies the Rules of Procedure of this Commission; however,
the Company will, in the alternative, bring the Application to the attention of its affected
customers through any other means directed by this Commission.
26. Communications and service of pleadings with reference to this
Application should be sent to the following:
Lisa D. Nordstrom Regulatory Dockets
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
[e-mail] [e-mail]
Matthew T. Larkin Timothy E. Tatum
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
[e-mail] [e-mail]
VII. REQUEST FOR RELIEF
27. Idaho Power respectfully requests that the Commission issue an order
approving an update to Schedule 55 based on the quantification of the 2016-2017 PCA,
resulting in an overall increase to current billed revenue of approximately $17.3 million
to become effective June 1 , 2016, as detailed in Attachment 2.
DATED at Boise, Idaho, this 151h day of April 2016.
Attorney for ldah
APPLICATION - 10
wer Company
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-16-08
IDAHO POWER COMPANY
ATTACHMENT 1
PROPOSED TARIFF
(clean and legislative formats)
CLEAN FORMAT
Idaho Power Company
I.P.U.C. No. 29, Tariff No. 101
APPLICABILITY
Tenth Revised Sheet No. 55-1 Cancels Ninth Revised Sheet No. 55-1
SCHEDULE 55 POWER COST ADJUSTMENT
This schedule is applicable to the electric energy delivered to all Idaho 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 2.0907 cents per kWh, which is comprised of Category 1 power costs of
1.0963 cents per kWh, Category 2 power costs of 0.9138 cents per kWh and Category 3 power costs of
0.0806 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 is 2.4435
cents per kWh, which is comprised of Category 1 power costs of 1.3066 cents per kWh, Category 2
power costs of 1.0839 cents per kWh and Category 3 power costs of 0.0530 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 0.2765 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
¢ per kWh (0.0280) (0.0267) (0.0269) (0.0355) (0.0210) (0.0183)
IDAHO Issued per Order No.
Effective - June 1, 2016
Issued by IDAHO POWER COMPANY Timothy E. Tatum, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, Idaho
Idaho Power Company
1.P.U.C. No. 29, Tariff No. 101
EARNINGS SHARING (Continued)
Fifth Revised Sheet No. 55-2
Cancels
Fourth Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
9T
15
19S
19P 19T 24 40 41
42
26
29
30
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary Large Power Service - Transmission Agricultural Irrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Monthly Credit
Micron
Simplot
DOE
(0.0198)
(0.0610)
(0.0182)
(0.0161)
(0.0154) (0.0229) (0.0251) (0.0389)
(0.0178)
($5, 729.44)
($2,162.14)
($2,290.34)
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.
Schedule
1
3
5
7
9S 9P
9T
15
19S
19P
19T
24 40 41 42
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 Irrigation Service Unmetered General Service Street Lighting Traffic Control Lighting
Micron
Simplot
DOE
¢ per kWh (0.0284) (0.0284) (0.0284) (0.0284) (0.0284) (0.0284)
(0.0284)
(0.0284)
(0.0284)
(0.0284)
(0.0284)
(0.0284) (0.0284) (0.0284) (0.0284)
(0.0284) (0.0284)
(0.0284)
IDAHO
Issued per Order No.
Effective - June 1 , 2016
Issued by IDAHO POWER COMPANY Timothy E. Tatum, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, Idaho
Idaho Power Company
1.P.U.C. No. 29, Tariff No. 101
POWER COST ADJUSTMENT
Fourth Revised Sheet No. 55-3 Cancels
Third Revised Sheet No. 55-3
SCHEDULE 55 POWER COST ADJUSTMENT (Continued)
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 2 and 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
19S 19P 19T 24 40 41 42
26
29
30
EXPIRATION
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 Irrigation Service Unmetered General Service Street Lighting Traffic Control Lighting
Micron
Simplot
DOE
¢ per kWh
0.5623
0.5636
0.5633
0.5548
0.5693 0.5720 0.5704 0.5292 0.5721 0.5742 0.5749 0.5674
0.5651
0.5514
0.5725
0.5903 0.5903 0.5903
The Power Cost Adjustment included on this schedule will expire May 31, 2017.
IDAHO Issued per Order No. Effective - June 1 , 2016
Issued by IDAHO POWER COMPANY Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
LEGISLATIVE FORMAT
Idaho Power Company NimRTenth Revised Sheet No. 55-1 Cancels
I.P.U.C. No. 29, Tariff No. 101 eiQRtANinth Revised Sheet No. 55-1
SCHEDULE 55 POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho 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 2.�907 cents per kWh, which is comprised of Category 1 power costs of 1.40400963 cents per kWh, Category 2 power costs of 0.92@138 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 Projected Power Cost is
2.�435 cents per kWh, which is comprised of Category 1 power costs of 1.3�066 cents per
kWh, Category 2 power costs of 1.0479839 cents per kWh and Category 3 power costs of 0.05+JO
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 0.24-SJ765
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
¢ per kWh
(0.0-74J280)
(0.0&79267)
(0.0984269)
(0.0891355)
(0.0™210) (0.04ed183)
IDAHO Issued per Order No. � Effective - June 1, 201a§
Issued by IDAHO POWER COMPANY
Gregory \IV. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Idaho Power Company �Fifth Revised Sheet No. 55-2
Cancels I.P.U.C. No. 29, Tariff No. 101 �Fourth Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (Continued)
9T
15
19S
19P 19T 24 40 41 42
26 29
30
Large General Service - Transmission Dusk to Dawn Lighting Large Power Service - Secondary Large Power Service - Primary Large Power Service - Transmission Agricultural Irrigation Service Unmetered General Service Street Lighting
Traffic Control Lighting
Monthly Credit
Micron
Simplot
DOE
(0.0484198) (0.4§000610) (0.04eJ182) (0.0440161) (O.OJQ4154) (O.Oa-78229) (O.Oe39251) (O.m0389)
(0.04-ai178)
($14 ,629.275, 729.44)
($ 5,656.112.162.14)
($ 6,528.592,290.34)
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.
Schedule
1
3
5 7 9S 9P
9T 15
19S
19P
19T
24
40
41
42
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 Irrigation Service
Unmetered General Service Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
¢ per kWh (0.028e1)
(0.028e1) (0.028e1) (0.028e1)
(0.028e1)
(0.028e1)
(0.028e1)
(0.028e1)
(0.028e1)
(0.028e1)
(0.028e1)
(0.028e1) (0.028e1) (0.028e1) (0.028e1)
(0.028e1)
(0.028e1)
(0.0280:1)
IDAHO
Issued per Order No. JJJOO
Effective - June 1 , 2015§
Issued by IDAHO POWER COMPANY
Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Idaho Power Company +AifaFourth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird 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 2 and 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
19S
19P
19T 24 40 41 42
26
29 30
EXPIRATION
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 Irrigation Service Unmetered General Service Street Lighting Traffic Control Lighting
Micron
Simplot
DOE
¢ per kWh 0.43005623 0.�5636 0.�5633 0.�5548 0.44795693 0.4§495720
0.�5704
0.�5292 0.�5721 0.46025742 0.�5749 0.�5674 0.�5651 0.39005514 0.4§605725
0.5�903
0.�903 0.�903
The Power Cost Adjustment included on this schedule will expire May 31, 201ez.
IDAHO Issued per Order No. � Effective - June 1 , 2015§
Issued by IDAHO POWER COMPANY Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, Idaho
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-16-08
IDAHO POWER COMPANY
. .
ATTACHMENT 2
REVENUE IMPACT SUMMARY
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