20170417Application.pdf

Sfffi*.
,/rD An IDACORP Companv
:.lii ,':'.:i. i li PH L: 55
LISA D. NORDSTROi'
Lead Counsel
I [e-mail]
April 14, 2017
VIA HAND DELIVERY
Diane M. Hanian, Secretary
ldaho Public Utilities Commission
47 2 \N est Wash i ngton Street
Boise, ldaho 83702
Re Case No. IPC-E-17-06
2017-2018 Power Cost Adjustment - ldaho Power Company's Application
and Testimony
Dear Ms. Hanian
Enclosed for filing in the above matter please find an original and seven (7) copies
of ldaho Power Company's Application.
Also enclosed for filing are an original and eight (8) copies of the Direct Testimony of
Nicole A. Blackwell. One copy of the aforementioned testimony has been designated as
the "Reporter's Copy." ln addition, a disk containing a Word version of Ms. Blackwel!'s
testimony is enclosed for the Reporter.
Lastly, four (4) copies each of ldaho Power Company's press release, customer
notice, and direct mail postcard are also enclosed.
Very truly yours,
X,^--f,-
Lisa D. Nordstrom
LDN:csb
Enclosures
1221 W. ldaho St. (83702)
PO. Box 70
Boise, lD 83707
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 @ id a h opowe r. com
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO IMPLEMENT POWER
COST ADJUSTMENT ('PCA) P,q16a
FOR ELECTRIC SERVICE FROM JUNE
1,2017, THROUGH MAY 31,2018.
: - '- I- l,rf- i-\_ .:.'i:u
l, il; Fll I+'55
. irrl-.l':-- -;-;\\-Jt.
Attorney for ldaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
)
)
)
)
)
)
)
CASE NO. |PC-E-17-06
APPL!CATION
ldaho Power Company ("!daho Power" or "Company"), in accordance with ldaho
Code 61-502 and RP 052, hereby respectfully makes application to the tdaho Public
Utilities Commission ("Commission") for an order approving an update to Schedule 55
based on the quantification of the 2017-2018 Power Cost Adjustment ("PCA") to
become effective June 1, 2017 , for the period between June 1, 2017 , through May 31,
2018. The PCA rates listed on the proposed Schedule 55 include a $13 million refund
of previously collected Energy Efficiency Rider ("Rider") funds as approved in Order No.
33736 in Case No. IPC-E-16-33. The Company has included its proposed rates and
charges for electric service in the state of ldaho as Attachment 1 to this Application. lf
APPLICATION. 1
approved, the 2017-2018 PCA will result in an overall revenue increase of
approximately $10.6 million, or a 0.93 percent increase over current billed revenue.
In support of this Application, ldaho Power has filed the Direct Testimony of
Nicole A. Blackwell, Regulatory Analyst, which details the calculation of the proposed
2017-2018 PCA rates and explains the factors that impact this year's PCA
quantification.
I. BACKGROUND
1. ldaho Power is an ldaho 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 southern
ldaho and eastern Oregon. ldaho Power is subject to the jurisdiction of this
Commission in ldaho 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 costs of supplying energy to
ldaho Power customers. Neither ldaho Power nor its shareholders receive any financial
return from the PCA.
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
APPLICATION - 2
No. 30715 also approved changes to the Load GroMh Adjustment Rate ('LGAR"), third-
party transmission expense, the PCA forecast, and 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 lnvestment Tax
Credits (ADITC) if the Company's actual 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 actual 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 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-1 1-22 approving the settlement stipulation filed on December 12, 2011,
extending the revenue sharing mechanism through 2014 and modifying portions of the
previous accounting order. More specifically, Order No. 32424 approved modifications
to the sharing portion of the mechanism, which allowed 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 anyyearfrom 2012 through 2014, the earnings would
be shared equally between ldaho customers and the Company. The customer revenue
APPLICATION - 3
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 would 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 ldaho 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, ldaho 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
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.
!PC-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
APPLICATION - 4
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.
I. 2017-2018 PCA CALCULATTON
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.
11. 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
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 actua! 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
APPLICATION - 5
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 Ms. Blackwell describe and compute the
standard PCA rate to be effective June 1, 2017, through May 31 , 2018. The system-
level forecast of NPSE for the 2017-2018 PCA Year is $377,451,633, which is
$71,766,764 higher than the currently approved base level NPSE of $305,684,869 and
$19,903,893 higher than last year's forecast amount of $357,547,740. Compared to
last year, this year's PCA forecast reflects better-than-normal hydro conditions, resulting
in an increase in low-cost hydro generation available to serve customers. However, the
benefit from the improved hydro conditions is expected to be more than offset by an
increase in PURPA expenses, and higher coal-fired generation costs. The 2017-2018
PCA forecast component to be collected from ldaho customers is $66,914,308.
14. The True-Up deferral balance at the end of March 2017, with interest
applied, was $33,953,029. This charge to customers was largely driven by lower than
forecast hydro generation, which was met with higher than forecast market energy
purchases.
15. ln the True-Up of the True-Up, the Company under collected last year's
PCA True-Up balance by $2,257,651. The 2016-2017 combined PCA True-Up is a
decrease of $2,377,376 over the 2015-2016 combined PCA True-Up.
16. The Company's PCA rate for the 2017-2018 PCA Year is detailed in
Exhibit No. 3, column C, of Ms. Blackwell's testimony. The uniform PCA rate is
comprised of (1) the 0.4766 cents per kilowatt-hour ("kwh") adjustment for the 2017-
2018 projected power cost of serving firm loads under the current PCA methodology
and 95 percent sharing, (2) the 0.2423 cents per kWh for the 2016-2017 True-Up
APPLICATION - 6
portion of the PCA, and (3) the 0.0161 cents-per-kWh for the True-Up of the True-Up.
The sum of these three components results in an approximate 0.7361 cents-per-kWh
charge for al! rate classes.
III. ADDITIONAL RATE ADJUSTMENTS
17. Pursuant to Order No. 33736 in Case No. IPC-E-16-33, the Company's
proposed rates exclude the annual Rider credit. The annual Rider credit was
established in Case No. IPC-E-13-20, and approved in Order No. 33000, to maintain the
revenue neutrality associated with the June 2014 update to the normalized level of
NPSE included in base rates. Order No. 33736 issued in Case No. IPC-E-16-33
reduced the Rider collection percentage from 4 percent of base rate revenues to 3.75
percent, effective April 1 ,2017. Due to the decrease in the Rider collection percentage,
the goal of revenue neutrality set forth in Order No. 33000 is no longer applicable.
18. The Company's proposed rates include a refund of $13 million of
previously collected Rider funds through the 2017-2018 PCA. Consistent with Order
No. 33736. The Company has allocated the $13 million refund of previously collected
Rider funds to individual customer classes based on each class's proportional share of
forecasted base revenues for the June 1, 2017 , through May 31 , 2018, PCA collection
period. This allocation method ensures that each customer class receives the Rider
credit in a similar proportion to the initia! Rider collection.
19. The Company's earnings in each year from 201 1 through 2015 resulted in
revenue sharing with ldaho customers totaling $121.2 million, either as a direct rate
offset in the PCA or as an offset to amounts that would have othenrise been collected in
rates. As described in greater detail in the direct testimony and exhibits of Ms.
Blackwell, the Company's 2016ldaho jurisdictional year-end ROE was 9.53 percent. ln
APPLICATION - 7
accordance with the terms of the modified revenue sharing mechanism approved by
Order No. 33149, the Company's ldaho jurisdictional year-end ROE fell below the 10.0
percent ROE threshold for revenue sharing. Therefore, the 2017-2018 PCA will not
include a revenue sharing component.
IV. PROPOSED 2017-2018 PCA RATE INCREASE
20. The 2017-2018 total PCA amount (including a $13 million refund of
previously collected Rider funds), as measured from the currently approved base level
NPSE, is $90.1 million. This represents an increase in total billed revenue of $10.6
million, an increase of 0.93 percent.
21. 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 ldaho.
22. 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 $10.6 million more from June 2017 through May
2018 than the PCA rates currently in effect.
V. MODIFIED PROCEDURE
23. 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 technica! hearing is required, the
Company stands ready to present its testimony and support the Application in such
hearing.
APPLICATION - 8
VI. COMMUNICATIONS AND SERVICE OF PLEADINGS
24. ln conformance with RP 125, this Application will be brought to the
attention of ldaho 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. To ensure that all customers are notified in a timely
manner and have sufficient time to submit comments, ldaho Power is sending a direct
mail postcard to a subset of customers that receive their bill toward the end of the
processing time for this case. As such, all customers will receive a bill insert and/or the
direct mai! postcard mailed no later than May 19,2017 .
25. The Company has also prominently displayed its intent to file the PCA on
its website since March 15, 2017. Upon filing, this web graphic will link directly to the
PCA press release and bil! insert. ldaho 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 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
ldaho Power Company
1221West Idaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
I no rd strom @ id ahopowe r. co m
TamiWhite
Timothy E. Tatum
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
dockets@ idahooower.com twhite@ida hopower.com
ttatum@ id ahopower. com
APPLICATION - 9
VII. REQUEST FOR RELIEF
27. ldaho Power respectfully requests that the Commission issue an order
approving an update to Schedule 55 based on the quantification of the 2017-2018 PCA,
resulting in an overal! increase to current billed revenue of approximately $10.6 mlllion
to become effective June 1,2017 , as detailed in Attachment 2.
DATED at Boise, tdaho, this 14th day of April2017.
D
Attorney for ldaho Power Company
APPLICATION - 1O
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. !PC-E-17-06
IDAHO POWER COMPANY
ATTACHMENT 1
PROPOSED TARIFF
(clean and legislative formats)
CLEAN FORMAT
ldaho Power Company Eleventh Revised Sheet No. 55-1
Cancels
|.P.U.C. No. 29. Tariff No. 101 Tenth 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 2.0838 cents per kWh, which is comprised of Category 1 power costs of
1 .0927 cents per kWh, Category 2 power costs of 0.9108 cents per kWh and Category 3 power costs of
0.0803 cents per kWh.
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 2.5708
cents per kWh, which is comprised of Category 1 power costs of 1.2815 cents per kWh, Category 2
power costs of 1.2365 cents per kWh and Category 3 power costs of 0.0528 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
yeafs approved True-Up revenues and actual revenues collected. The total True-up is 0.2585 cents
per kWh.
EARNINGS SHARING
Order Nos. 30978, 32424, and 33149 directed the Company to share a portion of its earnings
above a certain threshold with customers through the annual Power Cost Adjustment. The Company's
2016 earnings were below the prescribed threshold resulting in a credit of 0.0000.
Schedule Description d per kWh1 ResidentialService 0.00003 Master Metered Mobile Home Park 0.00005 Residential- Time-of-Day Pilot Plan 0.00007 SmallGeneralService 0.000095 Large General Service - Secondary 0.00009P Large GeneralService - Primary 0.0000
IDAHO
lssued per Order No
Effective - June t, ZA'n
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 55-2
Cancels
|.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (Continued)
.00
.00
.00
$0
$o
$o
26
29
30
9T
15
195
19P
197
24
40
41
42
1
3
5
7
9S
9P
9T
15
19S
19P
197
24
40
41
42
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
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 lrrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
(0.057e)
(0.0543)
(0.0565)
d oer kWh
(0.1148)
(0.10e7)
(0.1107)
(0.1463)
(0.0864)
(0.0750)
(0.0846)
(0.2486)
(0.0746)
(0.0661)
(0.0625)
(0.0e3e)
(0.1032)
(0.1633)
(0.0730)
The following rate schedules will receive a rate credit associated with the refund of EE Rider
funds in the form of a cents per kWh rate.
Schedule
26
29
30
IDAHO
lssued per Order No.
Effective - June 1,2017
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fifth Revised Sheet No. 55-3
Cancels
|.P.U.C. No. 29. Tariff No. 101 Fourth 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) 1OO 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 refund of EE Rider funds.
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules
and Special Contracts are shown below. 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 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 lrrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
d per kWh
0.6213
0.6264
0.6254
0.5898
0.6497
0.6611
0.6515
0.4875
0.6615
0.6700
0.6736
0.6422
0.6329
0.5728
0.6631
1
3
5
7
9S
9P
9T
15
19S
19P
197
24
40
41
42
26
29
30
0.6782
0.6818
0.6796
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31,2018
IDAHO
lssued per Order No.
Effective - June l, ZA1J
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
LEGISLATIVE FORMAT
I tOano Power Company +enthEleventh Revised Sheet No. 55-1
Cancels
I |.P.U.C. No. 29. Tariff No. 101 AlinthTenth 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 2.0gO7g3E cents per kWh, which is comprised of Category '1 power costs of
1.09632 cents per kWh, Category 2 power costs of 0.913808 cents per kWh and Category 3 power
costs of 0.08063 cents per kWh.
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.re5708. cents per kWh, which is comprised of Category 1 power costs of 1.30662815 cents per
kWh, Category 2 power costs of 1.08392365 cents per kWh and Category 3 power costs of 0.0ffi28
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 Tru+'up is 0.27€5585
cents per kWh.
EARNINGS SHARING
Order Nos. 30978. #32424. and 33149 directed the Company to share a portion of its
earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Comnanv's 2O 1 6 earninos were below the orescribed threshold resultino in a credit of 0.0000.The
fellewing rate sehedules will reeeive a rate reduetien benefit asseeiated with the Gempany's 2014
eerni
Schedule Descriotion
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 oer kWh
€-028e}4.0900(@.0000(ruQ
(oo355)0.0000
(e€21€)0.0000
€€{€q0.0000
1
3
5
7
9S
9P
IDAHO
lssued per Order No.33526
Effective - June 1,20192
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
I lOano Power Company F+frhsixth Revised Sheet No. 55-2
Cancels
I I.P.U.C. No. 29. Tariff No. 101 FbudhFifth Revised Sheet No. 5gF2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (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
9T
15
19S
19P
197
24
40
41
42
(ro
€=e6{o}4.0000
€s{€2}0.0000(so16$a-4000
(s0154)9.0000
(0^0229)0.0000
(0.02504.0000
€o48q4.0000(ro
{$s#eg44)$0.00
{$2#62J4)$o.oo
{$2#90,34)$0.oo
26
29
30
FUNDS
Thefollowingratescheduleswillreceivearate@ssociatedwiththe
tr€n@1gfund of DSMEE Rider funds in the form of a cents per kWh rate.
Schedule 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 I rrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
d per kWh
(0.e38+1r+e)
(0.e38+1097)
(0.028+1roz1
(0.028+L+Oe1
(0.0ecaos64)
(0.oacagzso1
(0.oac+oe+01
(0.oas+2+e6)
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1
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IDAHO
lssued per Order No. 33526
Effective - June 1,20162
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
I tOano Power Company F€u*hFifth Revised Sheet No. 55-3
Cancels
I |.P.U.C. No. 29. Tarffi No. 101 ThiCFourth Revised Sheet No. 5$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) 1OO 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
inCategory3;4)theTrue-ups;5)EarningsSharing;and6)thet@ofDSMEERiderfunds.
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules
and Special Contracts are shown below. The ratee belew de net inelude the menthly Earnings Sharing
eredits fer eaefi ef the Speeial Centraet eustemers (SehedCee ^6' 29r 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 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 lrrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
d per kWh
0.562@130.@0.@254
0.554858980.569W
0.572e0(i1'!.
0.57e465150.w
0.57216615
0.5712 700
0.57196736
0.59146,422
0.565{€329
0.w5728
0.#56631
1
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15
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19P
197
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0.59$681r
0.59036796
EXPIRATION
I fne Power Cost Adjustment included on this schedule will expire May 31,20179.
IDAHO
lssued per Order No. 33526
Effective - June 1,20167
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
BEFORE THE
IDAHO PUBLIG UTILITIES COMMISSION
GASE NO. IPC-E-17-06
IDAHO POWER COMPANY
ATTACHMENT 2
REVENUE IMPACT SUMMARY
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