20211001Application.pdf

LISA D. NORDSTROM
Lead Counsel
[e-mail]
October 1, 2021
VIA ELECTRONIC FILING
Jan Noriyuki, Secretary
Idaho Public Utilities Commission
11331 West Chinden Blvd., Building 8
Suite 201-A
Boise, Idaho 83714
Re: Case No. IPC-E-21-32
In the Matter of Idaho Power Company’s Application for Approval to Modify Its
Demand Response Programs
Dear Ms. Noriyuki:
Attached for electronic filing, pursuant to Order No. 35058, is Idaho Power
Company’s Application in the above entitled matter.
Also attached is the Direct Testimony of Quentin Nesbitt and Jared Ellsworth filed in
support of the Application. A Word version of the testimony is also attached for the court
reporter.
If you have any questions about the attached documents, please do not hesitate to
contact me.
Very truly yours,
Lisa D. Nordstrom
LDN:sg
Attachments
RECEIVED
2021 OCT 01 PM 4:00
IDAHO PUBLIC
UTILITIES COMMISSION
APPLICATION- 1
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

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR
APPROVAL TO MODIFY ITS DEMAND
RESPONSE PROGRAMS.
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CASE NO. IPC-E-21-32

APPLICATION

To ensure Idaho Power ("Idaho Power" or "Company") has a portfolio of cost-
effective demand response (“DR”) programs available to reduce summer peak-hour
electricity demand, the Company proposes several DR program modifications to address
changes in system need and operations that have occurred since the Commission’s last
holistic DR review in 2013. Idaho Power respectfully applies to the Idaho Public Utilities
Commission ("Commission") pursuant to Idaho Code §§ 61-501 and -502 for authority
to: 1) modify its DR programs, 2) implement associated revised tariff schedules, and
3) establish a revised cost-effectiveness methodology to evaluate DR. If approved, the
proposed changes are intended to supersede the terms of settlement agreement
APPLICATION- 2
approved by Commission Order No. 329231 (“Settlement Agreement”) in 2013 in its
entirety.
In support of this Application, Idaho Power represents as follows:
I. IDAHO POWER’S DEMAND RESPONSE PORTFOLIO
1. Idaho Power is a public utility supplying retail electric service to more than
590,000 customers 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.
2. Purpose of DR. To minimize or delay the need to build new supply-side
resources the Company’s DR programs are designed to be available to meet potential
peak-hour system capacity deficits that typically occur during low hydro generation and
high load events on Idaho Power’s system. Because the deficits are expected to be
relatively large in magnitude but short in duration, it can be cost-effective to utilize DR
programs rather than building a supply-side resource that would only be required to
operate for a small number of hours.
3. DR Programs Offered. Idaho Power offers three DR programs; one
available to each of the three major customer classes. These programs represent
approximately 10 percent of Idaho Power’s system peak and comprise one of the largest
utility DR portfolios in the nation proportionate to its peak demand.
 The residential Air Conditioner (“A/C”) Cool Credit Program was started as a
pilot in 2002 and was fully implemented in 2003. Customers’ A/C units, or heat

1 In the Matter of the Continuation of Idaho Power Company’s A/C Cool Credit, Irrigation Peak Rewards,
and FlexPeak Demand Response Programs for 2014 and Beyond, Case No. IPC-E-13-14, Order No.
32923 (Nov 12, 2013).
APPLICATION- 3
pumps, are controlled using switches that communicate via powerline carrier, and
the units are cycled by the Company during an event to reduce load.
 The Commercial & Industrial (“C&I”) Flex Peak Program (“Flex Peak”) began
in 2009 and was originally managed by a third-party contractor until Idaho Power
took over full administration of the program in 2015. Eligible C&I customers that
can offer load reduction of at least 20 kilowatts (“kW”) manually reduce their
nominated load when Idaho Power calls an event without use of direct load control
devices.
 The Irrigation Peak Rewards Program is offered to Schedule 24, Agricultural
Irrigation Service, customers in the Company’s service area. It is Idaho Power’s
largest DR program in terms of capacity. Customers can participate with either a
manual or automatic dispatch option based on the configuration of their equipment
when the Company interrupts irrigation pumps during a called event.
4. DR Portfolio Capacity. Idaho Power’s DR portfolio capacity and costs for
the last five summer seasons are found in Table 1 below. As reported in the Demand-
Side Management (“DSM”) Annual Reports since 2016, the individual DR programs and
the overall DR portfolio have been cost-effective each year.

APPLICATION- 4
Table 1: 5-Year Summary of Demand Response Load Reduction, Capacity and
Cost by Jurisdiction

Year
System
Max Load
Reduction
(MW)
Idaho
Capacity
(MW)
Oregon
Capacity
(MW)
System
Capacity
(MW)
Idaho
Total Cost
Oregon
Total
Cost
Total
System
Cost
2020 336 346 20 366 $7,296,376 $418,536 $7,714,912
2019 333 376 21 397 $7,808,979 $467,217 $8,276,196
2018 359 367 16 383 $7,887,176 $282,243 $8,169,419
2017 383 374 20 394 $8,339,892 $477,637 $8,817,529
2016 378 372 20 392 $8,960,263 $511,104 $9,471,367

5. Current DR Program Requirements. Prompted by the lack of potential
near-term peak-hour deficits identified in the load and resource balance analysis prepared
for the 2013 IRP, Idaho Power filed a request in Idaho (Case No. IPC-E-12-29) for
authority to temporarily suspend two of its three DR programs (“A/C Cool Credit and
Irrigation Peak Rewards”) in December 2012.2
6. During the programs’ suspension, the Company worked with stakeholders
through a collaborative workshop process to evaluate and identify the best long-term
solution for either continuation or discontinuation of all three of Idaho Power’s DR
programs. This process resulted in settlement agreements being reached in both
states.3,4
7. Most notably, the Settlement Agreement includes several program specific
requirements, including marketing limitations, the method for determining cost-
effectiveness, and the Term of the Stipulation, as outlined below.5

2 The Flex Peak program (previously called FlexPeak Management) was not impacted by the Company’s
request because it was under contract with a third-party administrator at the time.
3 Case No. IPC-E-13-14, Order No. 32923.
4 In the Matter of Idaho Power Company, Staff Evaluation of the Demand Response Programs, Docket
No: UM 1653, Order No. 13-482 (Dec 19, 2013).
5 Case No. IPC-E-13-14, Motion to Approve Settlement Agreement, Attachment 2, pp. 2-3 (Oct 2, 2013).
APPLICATION- 5
This Agreement shall be in effect beginning on the date it is
approved by the Commission and shall apply to Idaho Power's
DR Programs for 2014 and beyond until a change occurs in
Idaho Power's system operations or cost-effectiveness of a
DR Program that would warrant reevaluation of the
Agreement’s terms. In such event Idaho Power will consult its
Energy Efficiency Advisory Group ("EEAG") and then make
an appropriate filing at the Commission. Similarly, a party to
this Agreement, may petition the Commission to open a
docket to reevaluate the terms of this Agreement if Idaho
Power experiences a change in system operations or the
cost-effectiveness of a DR Program so warrants.

As more fully described in Company witness Jared Ellsworth’s pre-filed direct testimony,
the Company has experienced a change in system need and operations since the
Settlement Agreement was approved in 2013 and requests approval to modify the DR
programs.
II. 2021 IRP CAPACITY VALUATION
8. Current Valuation. Historically, the Company has evaluated the maximum
operation potential of its existing DR resources to meet the peak demand hour (peak load)
during the summer months of June through August throughout the 20-year Integrated
Resource Plan (“IRP”) planning horizon. This is consistent with how traditional supply-
side resources have been evaluated. When determining the capacity value of the
Company’s DR portfolio in the 2019 IRP, the calculation was based on the DR portfolio’s
ability to be utilized during the top one-hundred system load hours given the program
parameters.6
9. Proposed Valuation Using ELCC. The Company has adopted a risk-based
methodology, known as Effective Load Carrying Capability (“ELCC”), to evaluate the
capacity contribution of the Company’s existing resources, expected future resources

6 Idaho Power Second Amended 2019 IRP, Case No. IPC-E-19-19, pp. 48-9.
APPLICATION- 6
(including variable resources), and DR. This method evaluates the Company’s load and
resource balance at the time of the highest-risk hours, rather than only analyzing a
resource’s ability to meet peak load. The ELCC method still considers DR’s ability to
contribute capacity given the program parameters, but the hours of need are identified
using probabilistic and statistical methods as opposed to utilizing the top one-hundred
system load hours. As described in greater detail in Mr. Ellsworth’s testimony, the ELCC
calculation captures an individual generator’s contribution to the overall system reliability
and is primarily driven by the timing of high-risk Loss-Of-Load Probability (“LOLP”) hours.
10. LOLP. The primary hours of need for additional resources, or the highest-
risk LOLP hours, are no longer expected to align with the hours of Idaho Power’s system
peak load due to the increased penetration of solar, wind, and other variable resources
connected to the system. The LOLP is the statistical likelihood of system demand
exceeding the available generating capacity during a given time period, typically an hour.
11. In the preliminary 2021 IRP analyses, the highest LOLP hours have been
shown to shift to later in the day when solar sees an output reduction. As more solar
generation interconnects to the Company’s system, the Company expects the LOLP of
the evening solar-ramping-hours to increase and drive the need for additional resources
later in the day. While the time of the Company’s system peak load has historically
occurred between 5:00pm and 8:00pm, the highest-risk hours are expected to occur
between 7:00pm and 10:00pm, with some medium-risk hours leading up to 7:00pm and
from 10:00pm to 11:00pm, over the 2021 IRP planning horizon.
12. LOLE. As part of the ELCC calculation of a resource’s capacity contribution,
Idaho Power uses a Loss-of-Load Expectation (“LOLE”) of 0.05 days per year with all
APPLICATION- 7
market purchases set equal to zero. An LOLE of 0.05 days per year represents the
statistical probability that the Company’s available generation capacity is only insufficient
to serve demand one time in the span of 20 years. The Company ultimately chose to plan
for a 0.05 days per year LOLE threshold due to its dependence on hydroelectric resources
with variable water conditions and the more frequent occurrence of weather extremes.
13. When evaluating its existing DR programs utilizing the ELCC method, Idaho
Power determined that the existing DR programs, as structured, are not effective at
meeting system needs over the 20-year planning horizon. As described below, certain
parameters of the existing programs, specifically the current dispatch hours and program
season, limited the effectiveness of DR as a resource.
III. DEMAND RESPONSE PORTFOLIO OPERATING PARAMETERS
14. ELCC of Current DR Programs. Idaho Power conducted the ELCC analysis
on the current DR programs using an algorithm to identify how effectively the existing
programs meet future high-risk LOLP hours. As more fully described in Mr. Ellsworth’s
testimony, the ELCC of DR is obtained by first determining the perfect generation needed
to achieve an LOLE of 0.05 days per year without any DR on the Company’s system.
Next, the DR load shape is added to the system and the perfect generation is calculated
again. The ELCC of DR is then derived by taking the difference between the two perfect
generation values and dividing it by the DR portfolio’s nameplate capacity.
15. Using the current program parameters, the ELCC of a 380 MW DR portfolio
is estimated to be approximately 17 percent. That is, of the total 380 MW DR portfolio
capacity, only 65 MW can be relied upon to meet the highest-risk LOLP hours.
APPLICATION- 8
16. Sensitivity Analyses. Recognizing that the existing program parameters
may limit the effectiveness of DR, the Company conducted several sensitivity analyses
to determine the parameter adjustments needed to more effectively meet high-risk LOLP
hours. These analyses were performed by modifying several program criteria and
evaluating the impact to the ELCC of the DR portfolio. The program criteria studied for
each program included events per week, events per season, time available, length of
program season, and total hours dispatched per week.
17. The sensitivity analyses concluded that the dispatch times available and the
length of program season were the two parameters that had the highest impact on the
ELCC of DR. Therefore, the proposed parameters that more effectively meet future high-
risk LOLP hours were determined as outlined in Table 2 below.
Table 2. Current and Proposed Demand Response Program Parameters
Parameter Current Parameters Proposed Parameters
Events per Week 15 hours 16 hours
Events per Season 60 hours 60 hours
Time Available 1:00pm to 9:00pm 3:00pm to 11:00pm
Season Dates June 15th to August 15th June 15th to September 15th
Holidays No holidays No holidays

18. DR Effectiveness vs. Nameplate Capacity. The Company also analyzed
the effectiveness of DR capacity in 50 MW increments. As depicted in Chart 1, DR
effectiveness, and therefore ELCC, diminishes as DR nameplate capacity increases.

APPLICATION- 9
Chart 1. DR Effectiveness vs DR Nameplate Capacity

While the nameplate of the proposed DR portfolio is still unknown, the Company
estimates the approximate ELCC of a DR portfolio with the proposed parameters to be
56 percent with a 380 MW nameplate capacity. This would improve the portfolio’s
effectiveness by approximately 40 percent over the current DR program parameters.
IV. PROPOSED DEMAND RESPONSE PROGRAM MODIFICATIONS
19. As informed by the LOLE and ELCC analyses, the proposed changes to the
DR program parameters are designed to more effectively meet high-risk hours. Table 3
below summarizes the primary program components and highlights the overall proposed
parameter changes to the Company’s three DR programs that are more fully described
in Mr. Nesbitt’s testimony. The available event days and available event times vary slightly
between individual programs, but the table includes the full windows for all programs
combined.

0
50
100
150
200
250
300
350
50 100 150 200 250 300 350 400 442 492
DR
 Ef
f
e
c
t
i
v
e
n
e
s
s
 (M
W
)
DR Nameplate (MW)
DR Effectiveness
Test Year 1 Test Year 2 Test Year 3 Test Year 4 Average
APPLICATION- 10

Table 3: General Summary of Proposed DR Program Parameter Changes
Parameter Current Pro ram Proposed Pro ram Chan e
Season June 15th to August
15th
June 15th to
September 15th
Season end date
extended 1 month to
September 15th
Available
Event Days
Weekdays and
Saturdays
No Sundays or
Holidays (July 4th)
Weekdays and
Saturdays
No Sundays or
Holidays (July 4th &
Labor Da
No Change
Includes the additional
Labor Day Holiday
under the expanded
season
Available
Event Times 1:00pm to 9:00pm 3:00pm to 11:00pm Shifted start and end
times b 2 hours
Event
Maximum
Maximum 4 Hours
per Da
Maximum 4 Hours
per Da No Change
Weekly
Maximum
No More than 15
Hours in a Week
No More than 16
Hours in a Week
Increased weekly
maximum b 1 hou
Minimum
Season
Events
3 Events 3 Events No Change
Season
Maximum
Maximum 60 Hours
for Pro ram Season
Maximum 60 Hours
for Pro ram Season No Change

20. The ELCC analysis indicated that the program season and the available
event times were the variables that had the largest impact on increasing the effectiveness
of the DR programs. Therefore, Idaho Power requests to extend the program season one
month from August 15th to September 15th to capture high-risk hours later in the summer,
and shift the available event times by two hours to capture the highest-risk hours occurring
later in the evening as renewable resources are added to the system.
21. Idaho Power seeks to adjust the weekly maximum hours the DR programs
are available by one hour (from fifteen hours per week to sixteen hours per week) to
increase effectiveness and to better align with the event duration maximum of four hours.
This change maximizes the availability of weekly DR dispatch that Idaho Power’s Load
Serving Operations (“LSO”) group can utilize. The available event days, the event
APPLICATION- 11
maximum, the minimum season events, and the season maximum remain unchanged as
modifying these parameters were found to have a minimal impact on increasing the ELCC
of DR.
22. Stakeholder Engagement. As discussed in Company witness Quentin
Nesbitt’s pre-filed direct testimony, the Company held 10 formal touchpoints, with
Commission Staff, the EEAG, the Integrated Resource Plan Advisory Council (“IRPAC”),
and customer groups, plus several informal conversations with stakeholders to solicit
feedback on the proposed DR programs. The Company also conducted a customer
survey with current and potential DR program participants.
23. Expected Program Participation. The results of this outreach indicated that
current and prospective participants may be less willing or able to participate as the time
period requested shifts into the later hours of the day. The most dramatic decrease came
from the Irrigation Peak Rewards participants as only 30 percent of survey respondents
said they were able to participate between 7:00pm and 11:00pm. While the Company
anticipates there will be an impact to DR participation as a result of the parameter
changes, it is difficult to quantify the exact capacity impact the updates will have on the
DR programs at this time.
24. Participant Compensation. To help minimize a potential decrease in
customer participation, Idaho Power proposes to increase participant compensation
under the proposed programs as compared to the current program parameters and
incentives. Table 4 below shows the proposed changes for each of the three programs.

APPLICATION- 12

Table 4: Summary of Proposed Demand Response Program Design Changes

25. Recognizing it may be more difficult for some customers to participate in the
later evening hours, the Company is proposing an increase in the variable incentive after
four events for the Flex Peak program. Because the Flex Peak program pays its
participants weekly based on nominated kW regardless of whether an event is called,
participants will see an increase in the overall fixed incentive they receive due to the
proposed program being extended by one month.
26. Under the Company’s proposal, A/C Cool Credit program participants will
receive an additional fixed incentive payment with the extension of the program to
September 15th with no change to the monthly incentive amount.
Event
Duration
Event
Window
Min. # of
Events
Event
Notification Fixed Incentive Variable
Incentive
Incentive
Adjustment
Fl
e
x

P
e
a
k

Existing 2-4 hours 2:00 to
8:00pm 3 events 2 hours prior
to event
$3.25 per kW per
week =
$29.25 per kW per
season
$0.16 per kWh
after 3rd event
$2.00 per kW not
achieved/event &
$0.25 after 3rd
event
Proposed
Option
2-4
hours
3:00 to
10:00pm 3 events
4 hours
prior to
event
$3.25 per kW per
week =
$42.25 per kW per
season
$0.20 per
kWh after 4th
event
$2.00 per kW not
achieved per
event
A/
C

C
o
o
l

C
r
e
d
i
t

Existing Up to 4
hours
Not
defined 3 events None $5.00 per month =
$15.00 per season None None
Proposed
Option
Up to 4
hours
Not
defined 3 events None $5.00 per month =
$20.00 per season None None
Ir
r
i
g
a
t
i
o
n

P
e
a
k

R
e
w
a
r
d
s

Existing Up to 4
hours
1:00 to
9:00pm 3 events 4 hours prior
to event
$5.00 per kW & 0.76¢
per kWh, 2 months =
$16.00 per kW per
season
$0.148 per
kWh after 3rd
event &
$0.198 for
9:00pm option
$5.00 per kW per
opt out & $1.00
per kW after 3rd
event
Proposed
Option
Up to 4
hours
3:00 to
11:00PM 3 events
4 hours
prior to
event
$5.25 per kW & 0.80¢
per kWh, 3 months =
$25.20 per kW per
season
$0.18 per
kWh after 4th
event & $0.25
for 11:00pm
option
$6.25 per kW per
opt out
APPLICATION- 13
27. For the Irrigation Peak Rewards program, the Company is proposing a
higher monthly fixed incentive credit along with an increased variable incentive after the
fourth event, again recognizing it may be harder for customers to participate in the later
evening hours.
28. Number of Events. The Company proposes to keep the requirement of
three minimum events. As previously approved by the Commission, the three minimum
events per season help the Company test and improve program operations and execution
to ensure reliable capacity reduction is achieved when DR is called upon. 7 However, the
Company seeks to increase the threshold for the variable incentive payment for the Flex
Peak and Irrigation Peak Rewards programs from after three events to after four events
to align with the extension of the season and the overall increase in fixed incentives
customers will receive.
29. Removal of Program Marketing Limitations. The programs were previously
limited from growing during a time when the IRP analysis showed no near-term capacity
deficits, and the Settlement Agreement approved in 2013 dictated specific marketing
constraints on each of the DR programs.8 To allow Idaho Power to market and recruit
sufficient DR program participants to meet high-risk hours identified in the 2021 IRP
analysis, Idaho Power requests the Commission approve removal of the current
marketing limitation that is found in Schedule 23.
30. Adjusted Flex Peak Program Baseline kW Calculations. As more fully
described in Mr. Nesbitt’s testimony, the current Adjusted Baseline kW calculation for the
Flex Peak program is the sum of the Original Baseline kW and the Day of Load

7 Case No. IPC-E-13-14, Motion to Approve Settlement Agreement, Attachment 2, pp. 6-8.
8 Id, pp. 5-7.
APPLICATION- 14
Adjustment (“DOA”). The DOA is the difference between the Original Baseline kW
demand and the actual metered kW prior to an event. The DOA is used to account for a
customer using more or less energy than their Original Baseline kW on a given event day.
The Company’s current DOA takes the difference between the Original Baseline kW and
subtracts or adds the actual metered kW two hours before an event with a maximum
adjustment cap of 20 percent. This difference is then added or subtracted to each hour’s
Original Baseline kW to arrive at a participant’s Adjusted Baseline kW.
31. While the proposed Adjusted Baseline kW calculation will still incorporate
the Original Baseline kW and a DOA, the Company proposes a change to how the DOA
portion is applied to the Original Baseline kW. The proposed adjustment to the DOA uses
a scalar method given a four-hour advanced notification of an event. The Original
Baseline kW for each event hour will be divided by the Original Baseline kW for the hour
preceding the advanced notification to arrive at a scalar, or multiplier, for each individual
hour. Each hour’s scalar is then multiplied by the actual kW registered during the hour
preceding the event notification to calculate a participant’s Adjusted Baseline kW. The
Company believes this method is more accurate in calculating a customer’s baseline, and
therefore, results in more accurate calculations of customer demand reduction and
compensation.
32. Advance Notice of Program Events. The Company is proposing to increase
the two-hour advance notification period to four hours for the Flex Peak program based
on feedback from customers and to align with the Irrigation Peak Rewards program, which
will streamline the dispatch process for the LSO.
APPLICATION- 15
33. Opting Out of Program Events. The Company proposes to add a provision
in the Irrigation Peak Rewards program where opt-out fees can be waived in limited
circumstances when unplanned or planned outages of at least three hours in duration
occur up to twenty-four (24) hours before an irrigation DR event or there is a multiday
outage within seventy-two hours of an event. The Company believes adding this clause
provides additional flexibility in the execution of the program, implements a tool to mitigate
program attrition, and will help build and maintain positive relationships with customers.
The Company also proposes adding tariff language that allows it to charge an opt-out fee
to customers who override the dispatch command on their device.
34. Irrigation Small Pump Installation Fee. Because the Company is proposing
to open the Irrigation Peak Rewards program to all irrigation customers, the Company
seeks to add an installation fee for new participants that have smaller measured
horsepower pumps (therefore less load reduction) in the Irrigation Peak Rewards
Program to maintain program cost-effectiveness.
35. Irrigation Out-of-Demand Season Energy Credit. An Out-of-Demand
Season Energy Credit would apply to the portion of Irrigation Peak Rewards participants
whose billing cycles do not align with the proposed DR season end date of September
15th. The irrigation season, as defined in Schedule 24, begins with the meter read date of
the May billing period and ends with meter read date for the September billing period.
Further, the irrigation season (in-season) has a demand charge per kW of billing demand
where out-of-season does not. Therefore, some customer’s billing demand could end
before September 15th based on their billing cycle, and they would not receive a demand
credit as part of the fixed incentive for their participation in the Irrigation Peak Rewards
APPLICATION- 16
program.
36. The addition of an Out-of-Demand Season Energy Credit would
appropriately compensate these participants and is structured so the demand portion of
the fixed incentive is paid using a dollar per kWh value. The proposed Out-of-Demand
Season Energy Credit is calculated to be equivalent between customers who will receive
a demand credit, because their in-season billing cycles end on or after September 15th,
and the customers whose out-of-season billing cycles start before September 15th.
37. Program Use During System Emergencies. Idaho Power requests to
modify the emergency use tariff language for the three DR programs to clarify that if an
emergency were to occur, the programs would be dispatched in accordance with NERC
standards and/or Idaho Power’s Rule J (Continuity, Curtailment and Interruption of
Electric Service).
38. Miscellaneous Tariff Changes. Because the last major revisions to the
tariffs occurred in 2013 as part of the Settlement Agreement, the Company proposes to
modify language or provide additional details in certain sections of the DR tariff schedules
based on its experience implementing the program provisions and answering participant
questions.
39. Proposed Tariff Schedules. The proposed tariffs for the Irrigation Peak
Rewards, Residential Air Condition Cycling Program, and Flex Peak Program (Schedules
23, 81, and 82 respectively) are included in clean and legislative versions as Attachment
1 to the Application.

APPLICATION- 17
V. DEMAND RESPONSE COST-EFFECTIVENESS
40. Current Method. Cost-effectiveness of the three DR programs is currently
determined based on the method outlined in the Settlement Agreement. The existing
method establishes the avoided cost for the three programs by calculating the avoided
capacity cost of a single 170 MW Simple Cycle Combustion Turbine (“SCCT”)
multiplied by an ELCC,9 levelized over 20 years, plus the corresponding deferred
energy savings for 60 program hours. The avoided capacity cost is updated with every
IRP planning cycle. If the total annual cost of operating the Company’s three DR
programs is less than the avoided cost outlined in the Settlement Agreement, the
programs are considered cost-effective during the annual DSM prudence review.
41. Proposed Method. The Company proposes to modify the avoided cost
calculation such that the DR programs are compared to an equivalent alternative
resource on a cost per kW per year basis to determine cost-effectiveness. Mr.
Ellsworth’s testimony outlines the components of the proposed alternate cost
calculation as the levelized capacity fixed costs of a proxy resource, the additional
system benefits of the proxy resource, and the ELCC of the annual DR nameplate
capacity compared to a proxy resource, where:
(Levelized Fixed Cost – Additional Benefits) x
ELCC of Annual DR Capacity Compared to Proxy Resource
= $ per kW year DR Avoided Cost

9 At the time the ELCC was developed in 2013, the Company studied the top 100 hours of peak demand
of each year over the prior five years. Of those top 100 hours, approximately 7 percent occurred outside
of program hours. As a result, an ELCC of 93 percent is currently applied to determine the value of
demand portion of the avoided capacity calculation. The purpose of the ELCC is to reflect the ability the
ability of a peaking resource, such as a SCCT, to be used year-round where the DR programs can only
be dispatched during certain hours between June 15th and August 15th each year.
APPLICATION- 18
42. The Company proposes to evaluate cost-effectiveness at both the
individual program and portfolio levels. A dollar per kW cost would be calculated
annually for each of the Company’s DR programs and the overall portfolio, assuming
the maximum 60 hours of operation. The per kW costs would then be compared to the
avoided cost value. Under Idaho Power’s proposed methodology, a program and a
portfolio would be considered cost-effective as long as their dollar per kW costs are
less than the avoided cost value.
43. Using 492 MW of traditional DR potential calculated from the Northwest
Power and Conservation Council assessment,10 the Company anticipates that the cost
of each modified program and the overall DR portfolio will be cost-effective at less than
$51.42 per kW per year. The Company also recognizes that near-term DR capacity will
most likely be less than the 492 MW. A lower capacity results in a higher ELCC, and a
higher ELCC value increases the $ per kW per year avoided cost in the proposed
equation.
44. DR Evaluation Timing. Although the Company intends to evaluate all
three components with every IRP planning cycle to establish baselines, it proposes to
update the values used in the cost-effectiveness calculation with every DSM annual
reporting cycle. All three components and cost-effectiveness will be reported in the
annual DSM report, and a request for a prudence determination on program costs will
be sought in each year’s DSM prudence case.

10 2021 Northwest Power Plan Supporting Material – Demand Response, Council Document 21-5
(September 2021) at https://www.nwcouncil.org/2021powerplan_demand-response.
APPLICATION- 19
VI. COMMUNICATONS
45. Communications and service of pleadings, with reference to this
Application should be sent to the following:
Lisa D. Nordstrom Connie Aschenbrenner
Lead Counsel Rate Design Senior Manager
Idaho Power Company Idaho Power Company
P.O. Box 70 P.O. Box 70
Boise, Idaho 83707 Boise, Idaho 83707
[e-mail] [e-mail]
[e-mail]
VII. MODIFIED PROCEDURE
46. Idaho Power believes that it would be appropriate to process this case by
means of Modified Procedure (i.e., by written submissions rather than by hearing) in
accordance with the provisions of RP 201-210 et seq. However, if the Commission
prefers another procedure for processing, the Company has pre-filed the direct testimony
of Company witnesses Jared Ellsworth and Quentin Nesbitt.
VIII. REQUEST FOR RELIEF
47. Idaho Power seeks to implement the changes described above for the 2022
demand response season that begins on June 15, 2022. Idaho Power anticipates that it
will need some lead time to finalize program marketing materials, engage with customers
on modified program parameters, conduct program workshops, and enroll customers in
preparation for the 2022 DR season. A Commission order received by February 15, 2022
would position the Company to best meet these timeframes.
48. For the reasons set forth above and in the supporting testimony, Idaho
Power respectfully requests that the Commission authorize Idaho Power to: (1) modify
its DR programs, 2) implement associated revised tariff schedules, and 3) establish a
APPLICATION- 20
revised cost-effectiveness methodology to evaluate DR as described above to
supersede the Settlement Agreement approved by Commission Order No. 32923 in
its entirety.
DATED at Boise, Idaho, this 1st day of October 2021.

LISA D. NORDSTROM
Attorney for Idaho Power Company

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-32

IDAHO POWER COMPANY

ATTACHMENT 1

PROPOSED SCHEDULES 23, 81, and 82

(Clean and Legislative Formats)

CLEAN FORMAT
Idaho Power Company Eighth Revised Sheet No. 23-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)

PURPOSE

The Irrigation Peak Rewards Program (the Program) is an optional, supplemental service that
permits participating agricultural irrigation Customers taking service under Schedule 24 to allow the
Company to turn off specific irrigation pumps with the use of one or more Load Control Devices. In
exchange for allowing the Company to turn off specified irrigation pumps, participating Customers will
receive a financial incentive for load reductions during the calendar months of June, July, August, and
September for each metered service point (Metered Service Point) enrolled in the Program.

AVAILABILITY

Service under this schedule is available on an optional basis to Customers with a Metered Service
Point or Points receiving service under Schedule 24 where the Metered Service Point serves a water
pumping or water delivery system used to irrigate agricultural crops or pasturage.
The Company shall have the right to select and reject Program participants at its sole discretion
based on criteria the Company considers necessary to ensure the effective operation of the Program.
Selection criteria may include, but will not be limited to, Billing Demand, location, pump horsepower,
pumping system configuration, or electric system configuration. Past participation does not ensure
selection into the Program in future years. Participation may be limited based upon the availability of
Program equipment and funding.

Each eligible Customer who chooses to take service under this optional schedule is required to
enter into a Uniform Irrigation Peak Rewards Service Application/Agreement (Agreement) with the
Company prior to being served under this schedule. The Agreement will grant the Company or its
representative permission, on reasonable notice, to enter the Customer’s property to maintain one or
more Load Control Devices on the electrical panel servicing the irrigation equipment associated with the
Metered Service Points that are enrolled in this Program and to allow the Company or its representative
reasonable access to the Load Control Device(s). By entering into the Agreement, each Customer also
agrees to not increase for the sole purpose of participating in the Program the capacity, horsepower (HP)
or size of the irrigation system served by the Company.

PROGRAM DESCRIPTION

Service under this optional, supplementary Program permits the Company to turn off specified
irrigation pumps for a limited number of hours during the period of June 15 through September 15
(Program Season). The Company will utilize dispatchable Load Control Devices to turn off specific
irrigation pumps during Load Control Events. In limited applications, a select group of eligible Customers
will be permitted to manually interrupt electric service to participating irrigation pumps during Load Control
Events (See Manual Dispatch Option). In exchange for allowing the Company to interrupt service to
specified irrigation pumps, participating Customers will receive a financial incentive for usage that occurs
during the calendar months of June, July, August, and September for each Metered Service Point
enrolled in the Program.

DEFINITIONS

Notification of Program Acceptance. An interested Customer must sign and return to the
Company an Agreement specifying the Metered Service Point(s) to be included in the Program. If a
Customer is selected for participation in the Program, a notification of acceptance into the Program will

Idaho Power Company Eighth Revised Sheet No. 23-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)
DEFINITIONS (Continued)

be mailed to participants, which will include a listing of the Metered Service Point(s) that have been
enrolled.

Load Control Device. Load Control Device refers to any technology, device, or system utilized
under the Program to enable the Company to initiate the Load Control Event.

Load Control Event. Refers to an event under the Program where the Company requests or calls
for interruption of specific irrigation pumps either manually or with the use of one or more Load Control
Devices.

Program Season. The Program Season is the period June 15 through September 15 of each
year.

Program kW. The Program kW is the demand amount, as measured at the Customer’s meter in
kilowatts (kW) associated with the applicable billing period, that is multiplied by the applicable incentive
amount to determine the Demand Credit under the Automatic Dispatch Interruption Option. Under the
Manual Dispatch Interruption Option, the Program kW will be based upon the maximum measured
interval kW during the 24-hour period preceding 8:00 A.M. MDT the day of the announcement of a Load
Control Event, minus the average interval kW during an event.

Nominated Demand. Nominated Demand is the amount of demand that participants under the
Manual Dispatch Option must declare as planned to be available during Load Control Events.

Program kWh. The Program kWh is the energy amount, as measured at the Customer’s meter
in kilowatt-hours (kWh) associated with the applicable billing period, that is multiplied by the applicable
incentive amount to determine the Energy Credit under each Interruption Option.

Variable Program kWh. The Variable Program kWh is the demand amount for the associated
billing period, as measured at the Customer’s meter in kilowatts (kW) multiplied by the hours of
interruption for the Metered Service Point for each Load Control Event. The Variable Program kWh is
multiplied by the applicable variable incentive payment to determine the Variable Energy Credit under
each Interruption Option.
Variable Program kWh = Program kW x hours of interruption for each Load Control Event

Bill Credit. The Bill Credit is the sum of the Demand Credit and the Energy Credit applied to the
Customer’s monthly bills for usage that occurs during the calendar months of June, July, August, and
September of each calendar year. This amount may be prorated for the number of days during the
months of June, July, August, and September that fall in the Customer’s billing cycle to correspond with
the Program Season. The Bill Credit amount may be applied directly to participating Customers’ bills or
provided in the form of a check.

Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Demand
Credit is calculated by multiplying the Program kW by the demand-related incentive amount for the
Interruption Option selected by the Customer. The Demand Credit will be included on the Customer’s
monthly bills for usage that occurs during the calendar months of June, July, August, and September of
each year. This amount may be prorated for the number of days during the months of June, July, August,
and September that fall in the Customer’s billing cycle to correspond with the Program Season.
Demand Credit = Program kW x demand-related incentive amount
Idaho Power Company Eighth Revised Sheet No. 23-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

DEFINITIONS (Continued)

Energy Credit. The Energy Credit is an energy-based financial incentive provided in the form of
a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Energy
Credit is calculated by multiplying the Program kWh by the energy-related incentive amount for the
Interruption Option selected by the Customer. Customers identified to have an out-of-demand season
billing cycle will receive only an out-of-demand season energy credit for the applicable billing period. The
Energy Credit will be included on the Customer’s monthly bills for usage that occurs during the calendar
months of June, July, August, and September of each year. This amount may be prorated for the number
of days during the months of June, July, August, and September that fall in the Customer’s billing cycle
to correspond with the Program Season.
Energy Credit = Program kWh x energy-related incentive amount

Variable Energy Credit. The Variable Energy Credit is an energy-based financial incentive
provided for the Metered Service Point enrolled in the Program. The Variable Energy Credit is calculated
by multiplying Variable Program kWh by the energy-related incentive amount for the Interruption Option
selected by the Customer. The Variable Energy Credit is paid in the form of a check no later than 70
days after the Program Season. The Variable Energy Credit does not apply to the first four Load Control
Events.
Variable Energy Credit = Variable Program kWh x variable energy-related incentive amount

INTERRUPTION OPTIONS

Under the Interruption Options, the Company will dispatch remotely service interruptions to
specified irrigation pumps any Monday through Saturday during the Program Season between the hours
of 3:00 P.M. and 10:00 P.M. Mountain Daylight Time (MDT), excluding holidays (Standard Interruption).
Customers may elect to participate until 11:00 P.M. MDT (Extended Interruption) and will receive a larger
Variable Energy Credit. Service interruptions may last up to 4 hours per day and will not exceed 16 hours
per calendar week and 60 hours per Program Season. During each Program Season the Company will
conduct a minimum of three Load Control Events. Customers participating in the Automatic Dispatch
Option may not receive advance notification of a Load Control Event, but will be notified after the Load
Control Event begins. Customers participating in the Manual Dispatch Option will receive advance
notification at least 4 hours prior to a Load Control Event. The Company will provide notice of a Load
Control Event via the following communication technologies: telephone, e-mail and/or text message. If
prior notice of a pending Load Control Event has been sent, the Company may choose to revoke the
Load Control Event and will provide notice to Customers up to 30 minutes prior to the Load Control Event.

Customers who elect to participate in the Program may be eligible for one of the following
Interruption Options:

Automatic Dispatch Option. A dispatchable Load Control Device will be connected to the
electrical panel(s) serving the irrigation pumps associated with the Metered Service Points
enrolled in the Program. The Load Control Device utilized under the Automatic Dispatch Option

Idaho Power Company Eighth Revised Sheet No. 23-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

INTERRUPTION OPTIONS (Continued)

will provide the Company the ability to send a signal that will interrupt operation or not allow the
associated irrigation pumps to operate during dispatched Load Control Events. This option
requires that all pumps at the Metered Service Point be controlled.

Under the Automatic Dispatch Option, the Program kW will be based upon the
monthly Billing Demand, as measured in kW, for the associated Billing Period. The Program kWh
under this option will be based upon the monthly energy usage, as measured in kWh, for the
associated Billing Period.

Each time a customer chooses to opt-out of one of the Load Control Events a fee
of $6.25 per kW will be assessed based upon the current Billing Period’s kW. The opt-out fee will
not exceed the total Bill Credit for the Program Season. Any opt-out fee will be applied at the end
of the Program Season or after the applicable billing cycle closes. Opt-out fees may be waived
for circumstances involving planned or unplanned outages of 3 hours or more occurring within 24
hours of a Load Control Event or a multiday outage within 72 hours of an event. At its discretion,
the Company may assess an opt-out fee should it be determined the participant overrode the
command to the dispatch device thereby allowing the pump to run during the load control event.

Manual Dispatch Option. Customers are eligible to manually control Metered Service Points
of at least 1,000 cumulative HP, or Metered Service Points that have been determined by the
Company to be limited by load control device communication technology or installation
configuration. Under the Manual Dispatch Option, eligible Customers have the flexibility to
choose which irrigation pumps at a Metered Service Point will be interrupted during each
dispatched Load Control Event. Customers electing this option must notify the Company of their
Nominated Demand during the enrollment period prior to June 1 of each year.

Customers participating in the Manual Dispatch Option are required to provide no
less than their Nominated Demand during each Load Control Event. Each time a customer
chooses to provide less than their Nominated Demand during one of the Load Control Events, an
opt-out fee of $6.25 per kW will be assessed on the Nominated Demand not made available for
interruption. The opt-out fee will not exceed the total Bill Credit for the Program Season. Any
opt-out fee will be applied at the end of the Program Season or after the applicable billing cycle
closes. Opt-out fees may be waived for circumstances involving planned or unplanned outages
of 3 hours or more occurring within 24 hours of a Load Control Event or a multiday outage within
72 hours of an event.
Idaho Power Company Eighth Revised Sheet No. 23-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

INTERRUPTION OPTIONS (Continued)

Under the Manual Dispatch Option, the Program kW will be based upon the
maximum measured interval demand during the 24-hour period preceding 8:00 A.M. MDT the day
of the announcement of a Load Control Event, minus the average demand during an event, as
measured in kW over applicable load profile metering intervals. This applies to each Load Control
Event initiated during a Billing Period. If there are no Load Control Events during a Billing Period
then the Program kW will be the Nominated Demand. The Program kWh under this option will be
based upon a calculated value, as measured in kWh. The Program kWh will be calculated
separately for each Billing Period by multiplying the monthly Program kW by the ratio of the
monthly energy usage to the Billing Demand for the associated Billing Period.

INCENTIVE STRUCTURE

Incentive payments under the Interruption Options will be determined based on a fixed payment
and a variable payment. The fixed portion of the incentive payment will be paid through a Bill Credit and
the variable portion will be paid by check no more than 70 days after the end of the Program Season.
The first four Load Control Events will not be subject to the Variable Energy Credit. The variable payment
will be based on the number of hours a participant’s pump is interrupted during the Program Season and
their associated Program kW after the first four Load Control Events.

INSTALLATION FEES

An Installation Fee of $500 will be required for any new participating Metered Service Point with
measured horsepower of 30 or less. The Installation Fee is non-refundable except when a Customer
elects early termination and prior to the installation of a load control device at their pump location.

TERM OF AGREEMENT AND TERMINATION

The term of the Agreement, as it applies to each Metered Service Point accepted for participation,
shall commence on the date the Agreement is signed by both the Customer and the Company and shall
automatically renew on March 15 of each calendar year unless notice of termination is given by either
party to the other prior to the annual renewal date or unless otherwise terminated as follows:

1. A Customer may terminate the participation of a Metered Service Point and avoid the Termination
Fee by notifying the Company or its representative before the Program Season.
Fixed Incentive Payment Variable Incentive Payment

Demand Credit
($ per Program kW)
Energy Credit
($ per Program kWh)
Energy Credit ($
per Program
kWh) for Out-of-
Demand
Season Billing
Cycles
Standard
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
Extended
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
$5.25 $0.008 $0.021 $0.18 $0.25
Idaho Power Company Eighth Revised Sheet No. 23-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

TERM OF AGREEMENT AND TERMINATION (Continued)

2. A Customer who terminates the participation of a Metered Service Point anytime between
June 15 and September 15 of each calendar year shall pay the Company a Termination Fee.
This fee will be included on the Customer’s monthly bill following termination of participation. The
Customer’s Bill Credit shall be prorated for the number of days in that month the Customer
satisfactorily participated in the Program. Upon terminating participation of a Metered Service
Point under the provisions of item 2, the Customer may not re-enroll the Metered Service Point
into the Program until the following calendar year and the applicable Termination Fee has been
paid in full.

Termination Fees:

Automatic Dispatch Option: $500.00 per Metered Service Point terminated under item 2

3. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s
ability to initiate a Load Control Event at a Metered Service Point, the Agreement as it applies to
that Metered Service Point will be automatically terminated. In addition, the Customer will be
subject to each of the following:

a. The Customer will be required to reimburse the Company for the cost of
replacement or repair of the Load Control Device(s), including labor and other related
costs.

b. An applicable Termination Fee, as provided under item 2, will be applied to the
Customer’s monthly bill following the termination of participation.

c. The Company will reverse any and all Demand Credits and/or Energy Credits
applied to the Customer’s monthly bill(s) for the Metered Service Point as a result of the
Customer’s participation in the Program during the current year.

Note: A service disconnection for any reason does not terminate the Agreement.

SPECIAL CONDITIONS

The provisions of this schedule do not apply for any time period that the Company utilizes a Load
Control Device installed under this Program to interrupt the Customer’s load for a system emergency in
accordance with NERC standards, Idaho Power’s Rule J, or any other time that a Customer’s service is
interrupted by events outside the control of the Company. The provisions of this schedule will not affect
the calculation or rate of the regular Service, Energy or Demand Charges associated with a Customer’s
standard service schedule.
Idaho Power Company Eighth Revised Sheet No. 23-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 Seventh Revised Sheet No. 23-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

Uniform Irrigation Peak Rewards Service
Application/Agreement

THIS AGREEMENT Made this ____ day of _________________________________, ______
between __________________________________________________________ hereinafter called
Customer, whose billing address is _____________________________________________________,
and IDAHO POWER COMPANY, a corporation with its principal office located at 1221 West Idaho Street,
Boise, Idaho, hereinafter called Company. This Agreement shall automatically renew on March 15 of
each calendar year unless notice of termination is given by either party to the other prior to the annual
renewal date. This Agreement is for the Metered Service Point(s) identified on the attached worksheet
(Worksheet):

The Customer designates the following person as the Customer’s authorized contact:

Authorized Contact: _________________________________________________________________
Phone: ______________________________________ Cell Phone: __________________________
Email: ____________________________________________________________________________

NOW, THEREFORE, The Parties agree as follows:

1. The Uniform Irrigation Peak Rewards Service Application/Agreement must be signed by the
Customer and the Customer must be the person who is responsible for paying bills for retail
electric service provided by the Company at the Metered Service Point(s) identified on the
Worksheet.

2. The Customer understands that the information concerning the Metered Service Point(s) on the
Worksheet is based on the best information currently available to the Company. The Bill Credit
amounts are estimates based on the previous year’s billing history for the Metered Service
Point(s) specified on the Worksheet. Customers without sufficient billing history will be provided
an estimated Bill Credit based on the stated cumulative horsepower at the Metered Service Point.
The Bill Credit estimates are provided for illustration purposes. The Customer agrees to specify
which Metered Service Point(s) listed on the Worksheet the Customer wishes to enroll in the
Program and the Interruption Option selected for each specified Metered Service Point. For
Metered Service Points enrolled in the Manual Dispatch Option the Customer must notify the
Company of Nominated Demand amounts by June 1 of each year.

Idaho Power Company Seventh Revised Sheet No. 23-8
Cancels
I.P.U.C. No. 29, Tariff No. 101 Sixth Revised Sheet No. 23-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)
Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

3. From time to time during the term of this Agreement and with prior reasonable notice from the
Company, the Customer shall permit the Company or its representative to enter the Customer’s
property on which the enrolled Metered Service Point(s) are located to permit the Company or its
representative to install, service, maintain and/or remove Load Control Device(s) on the electrical
panel that services the Customer’s irrigation pumps. The Load Control Device(s) may remain in
place on the Customer’s property upon termination of the Agreement unless the Customer
specifically requests removal.

4. The Customer understands and acknowledges that by participating in the Program, the Company
shall, at its sole discretion, have the ability to interrupt the specified irrigation pumps at the
Metered Service Point(s) enrolled in the Program according to the provisions of the Interruption
Option selected. The Company retains the sole right to determine the criteria under which a Load
Control Event is scheduled for each Metered Service Point. The Customer also understands and
acknowledges that if a Metered Service Point provides electricity to more than one irrigation
pump, each pump will be scheduled for service interruption simultaneously, excluding Metered
Service Points participating in the Program under the Manual Dispatch Option.

5. For the Customer’s satisfactory participation in the Program, the Company agrees to pay the
Customer the Demand Credit and/or Energy Credit corresponding to the Interruption Option
selected by the Customer. The Bill Credit included on the Worksheet is based upon the billing
history for the Metered Service Point(s) specified on the Worksheet, for the months of June, July,
August, and September of the prior year. The Bill Credit will be paid in the form of a credit on the
Customer’s monthly bill or provided in the form of a check. The Demand Credit may be prorated
for the months of June, July, August, and September depending on the Customer’s billing cycle.

Metered Service Points participating under the Manual Dispatch Option, will receive a Bill Credit
from the Company within 30 days of billing due to the extensive data analysis required to process
interval metering data. Any applicable Variable Energy Credits will be paid by check no more than
70 days after the end of the Program Season.

6. If the Customer terminates this Agreement anytime between June 15 and September 15 of the
current calendar year while the Metered Service Point(s) are still connected for service the
Customer may not re-enroll that Metered Service Point into the Program until the following
calendar year and the applicable Termination Fee has been paid in full.

Idaho Power Company Third Revised Sheet No. 81-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 81-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)

PURPOSE

The Residential Air Conditioner Cycling Program is an optional, supplemental service that
permits participating residential Customers an opportunity to voluntarily allow the Company to cycle
their central air conditioners with the use of a direct load control Device installed at their residence.
Customers will receive a monetary incentive for successfully participating in the Program during the Air
Conditioning Season.

DEFINITIONS

AC Cycling is the effect of the Company sending a signal to a Device installed at the Customer’s
residence and instructing it to cycle the Central Air Conditioning compressor for a specified length of
time.
Air Conditioning Season is the period that commences on June 15 and continues through
September 15 of each calendar year.

Central Air Conditioning is a home cooling system that is controlled by one or more centrally
located thermostats that controls one or more refrigerated air-cooling units located outside the
Customer’s residence.

Cycling Event is a period during which the Company sends a signal to the Device installed at
the Customer’s residence, which instructs the Device to begin AC Cycling.

Device is a direct load control device installed at a Customer’s residence that enables the
Company to conduct AC Cycling.

Notification refers to the Customer’s indication of intent to initiate or terminate participation in the
Program by either contacting the Company’s Customer Service Center, providing written notice or
submitting an electronic Application via the Company’s website.

Opt Out is the term used to describe the two times each Air Conditioning Season in which the
Customer may choose to temporarily not participate in AC Cycling by providing advanced Notification to
the Company.

Program Operation Area describes the area in which the Program will be offered to Customers
and is comprised of the Company’s service territory within the State of Idaho where the infrastructure
required to support AC Cycling has been installed and is operational.

Idaho Power Company Third Revised Sheet No. 81-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 81-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)
(Continued)

PROGRAM DESCRIPTION

1. At the Company’s expense, the Company or its representative will install a Device at the
Customer’s residence.

2. A financial incentive of $5.00 per month for each of the four months of June, July,
August, and September will be paid to each Customer who successfully participates in the Program.
This incentive will be paid in the form of a credit on the Customer’s monthly bill for each month that the
Customer successfully participates in the Program, beginning with the July bill and ending with the
October bill. Incentive payments are limited to one controlled Central Air Conditioning unit per metered
service point. Customers who have more than one Central Air Conditioning unit at a metered service
point may participate in the Program. A Device must be installed at each Central Air Conditioning unit.
However, no additional incentive will be paid.

3. The Company will send a signal to the Device to initiate a Cycling Event. A Cycling
Event may be up to four hours per day on any weekday during the Air Conditioning Season, excluding
holidays. A Cycling Event may occur over a continuous 4-hour period or may be segmented
throughout the day at the Company’s discretion in order to optimize available resources. Cycling
Events may occur up to 16 hours each week and will not exceed a total of 60 hours per Air Conditioning
Season. During each Air Conditioning Season, the Company will conduct at least three Cycling Events.
Mass memory meters or end-use meters may be installed on some Customers’ residences or Central
Air Conditioning units for program evaluation purposes. The residences or Central Air Conditioning
units selected for installation of the meter shall be at the Company’s sole discretion.

SPECIAL CONDITIONS

The Company is not responsible for any consequential, incidental, punitive, exemplary or
indirect damage to the participating Customer or third parties that results from AC Cycling, from the
Customer’s participation in the Program, or of Customer’s efforts to reduce peak energy use while
participating in the Program.

The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Device and any and all implied warranties are disclaimed.

The Company shall have the right to select the AC Cycling schedule and the percentage of
Customers’ Central Air Conditioning systems to cycle at any one time, up to 100%, at its sole
discretion.

The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer’s load for a system emergency in accordance with NERC standards, Idaho Power’s Rule J,
or any other time that a Customer’s service is interrupted by events outside the control of the Company.
The provisions of this schedule will not affect the calculation or rate of the regular Service or Energy
Charges associated with a Customer’s standard service schedule.
Idaho Power Company Second Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

PURPOSE

The Flex Peak Program (the Program) is a voluntary program that motivates Participants to
reduce their load during Company initiated demand response events. A participating Customer will be
eligible to receive a financial incentive in exchange for being available to reduce their load during the
calendar months of June, July, August, and September.

AVAILABILITY

The Program is available to Commercial and Industrial Customers receiving service under
Schedules 9, 19, or a Special Contract Schedule.

The Company shall have the right to accept Participants at its sole discretion based on criteria
the Company considers necessary to ensure the effective operation of the Program. Selection criteria
may include, but will not be limited to, total Program capacity, a Facility Site location, or amount of
capacity provided at a Facility Site.

To participate in the Program, a Customer must sign and return the Program Application and
worksheet provided by the Company specifying the Facility Site(s) to be enrolled in the Program. To
enroll in the Program, Customers must be capable of providing a minimum load reduction of 20 kW per
Facility Site or an aggregate reduction of 35 kW if participating under the Aggregated Option. If a Facility
Site is accepted for participation in the Program, a Notification of Program Acceptance will be mailed to
the Participant within 10 business days of the Company receiving the Program Application. Notification
of Program Acceptance will include a listing of the Facility Sites that have been enrolled.

PROGRAM DESCRIPTION

The Company will initiate Program Events for a maximum of 60 hours during June, July, August,
and September. During Program Events, Participants will be expected to reduce load at their Facility
Site(s). Participants will be eligible to receive a financial incentive in exchange for their reduction in load.

DEFINITIONS

Actual kW Reduction. The kilowatt (kW) reduction during a Program Event, which is the difference
between a Participant’s hourly average kW measured at the Facility Site’s meter and the corresponding
hour of the Adjusted Baseline kW.

Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment
amount.

Aggregated Option. Multiple Facility Sites belonging to a single Participant that are grouped
together per the customer’s request with a single Nominated kW for participation in the Program. Under
this option, the Company will sum the individual performance data from each enrolled Facility Site before
calculating any incentive amounts.

Idaho Power Company First Revised Sheet No. 82-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Business Days. Any day Monday through Friday, excluding holidays. For the purposes of this
Program, Independence Day and Labor Day are the only holidays during the Program Season. If
Independence Day falls on Saturday, the preceding Friday will be designated the holiday. If
Independence Day falls on Sunday, the following Monday will be designated the holiday.

“Day of” Load Adjustment. The difference between the Original Baseline kW and the actual
metered kW during the hour prior to the Participant receiving notification of an event. Scalar values will
be calculated by dividing the Original Baseline kW for each Program Event hour by the Baseline kW of
the hour preceding the event notification time. The scalars are multiplied by the actual event day kW for
the hour preceding the event notification time to create the Adjusted Baseline kW from which load
reduction is measured. The Adjusted Baseline kW for each hour cannot exceed the maximum kW amount
for any hour from the Highest Energy Use Days or the hours during the event day prior to event
notification.

Event Availability Time. Between 3:00 p.m. and 10:00 p.m. Mountain Daylight Time (MDT) each
Business Day.

Facility Site(s). All or any part of a Participant’s facility or equipment that is metered from a single
service location that a Participant has enrolled in the Program. For those Participants who have enrolled
under the Aggregated Option, Facility Site will refer to the combination of individual Facility Sites selected
for inclusion under the Aggregated Option.

Fixed Capacity Payment. The Weekly Effective kW Reduction multiplied by the Fixed Capacity
Payment rate (as described in the Incentive Structure section). Participants are paid based on the
average event kilowatt reduction.

Highest Energy Usage Days. The three days out of the immediate past 10 non-event Business
Days that have the highest sum total kW as measured across the Event Availability Time.

Hours of Event. The timeframe when the Program Event is called and Nominated kW is expected
to be reduced. The Hours of Event will not be less than two hours and will not exceed four hours.

Nominated kW. The amount of load expressed in kW that a Facility Site commits to reduce during
a Program Event.

Nominated kW Incentive Adjustment. An adjustment made when a Facility Site does not achieve
its Nominated kW for a given hour during a Program Event. The adjustment will be made for each hour
the Nominated kW is not achieved. The total Nominated kW Incentive Adjustment will not exceed the
total incentive amount for the Program Season (as described in the Incentive Structure section).

Idaho Power Company First Revised Sheet No. 82-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Notification of Program Acceptance. Written confirmation from the Company to the Participant.
The Notification of Program Acceptance will confirm each Facility Site enrolled in the Program, as well
as the Nominated kW amount for each Facility Site.

Original Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days
during the Event Availability Time, calculated for each Facility Site for each hour.

The following table provides an example of the calculation of the Original Baseline kW between hours of
3:00 p.m. and 10:00 p.m. using the (3) Highest Energy Usage Days of 5, 7, and 9.

Day 3‐4 PM 
(kW) 
4‐5 PM 
(kW) 
5‐6 PM  
(kW) 
6‐7 PM 
(kW) 
7‐8 PM 
(kW) 
8‐9 PM 
(kW) 

9‐10 PM 
(kW) 
Sum Total 
(kW)  
 1 3000 3100 3000 3200 3000 3200 3150 21650  
 2 3200 3100 3200 3200 3100 3300 3300 22400  
 3 3100 3200 3100 3100 3200 3100 3200 22000  
4 3250 3400 3300 3400 3300 3400 3200 23250 
5 3300 3400 3300 3400 3400 3500 3400 23700 
 6 3100 3000 3200 3100 3100 3200 3300 22000  
 7 3400 3300 3400 3300 3400 3300 3200 23300  
 8 3300 3200 3300 3300 3300 3200 3100 22700  
 9 3400 3500 3350 3400 3500 3400 3350 23900  
 10 3250 3300 3300 3200 3200 3200 3300 22750  

Original 
Baseline 
(kW) 3367 3400 3350 3367 3433 3400 

3317    
Participant. Any Customer who has a Facility Site that has been accepted into the Program.

Program Application. Written form submitted by a Customer who requests to enroll a Facility
Site in the Program.

Program Event. A time period when the Company requests or calls for reduction of the Nominated
kW.

Program Season. June 15th through September 15th of each year.

Program Week. Monday through Friday.

Idaho Power Company Second Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Variable Program kWh. The kWh savings amount calculated by multiplying the Actual kW
Reduction by each of the Hours of Event for the Facility Site during each Program Event beyond the first
four Program Events.

Variable Energy Payment. An energy-based financial incentive provided to the Participant. The
payment is calculated by multiplying the Variable Program kWh by the Variable Energy Payment Rate
(as described in the Incentive Structure section). The Variable Energy Payment does not apply to the
first four Program Events.

Weekly Effective kW Reduction. The average of the Actual kW Reduction for all events in a
Program Week or in the absence of a Program Event, the Weekly Effective kW Reduction will equal the
Nominated kW for that Program Week.

PROGRAM EVENTS

The Company will dispatch Program Events on Business Days during the Program Season
between the hours of 3:00 p.m. and 10:00 p.m. MDT. Program Events will last between two to four hours
per day and will not exceed 16 hours per calendar week and 60 hours per Program Season. During each
Program Season the Company will conduct a minimum of three Program Events. Participating
Customers will receive advance notification on or about four hours prior to the Program Event. The
Company will provide notice of a Program Event via the following communication technologies:
telephone, text message, and e-mail to the designated contact(s) submitted by the Participant in the
Program Application. If prior notice of a pending Program Event has been sent, the Company may
choose to revoke the Program Event initiation and will provide notice to Participants no less than 30
minutes prior to the Program Event.

REQUIREMENTS OF PARTICIPATING FACILITIES

Participants will have the flexibility to choose what equipment will be used to reduce the
Nominated kW during each Program Event. Participants must notify the Company of their Nominated
kW via the Program Application. Once the Program Season begins, the Participant must submit the
nomination change request form online (located at www.idahopower.com/flexpeak) via email by
Thursday at 10:00 a.m. MDT of the proceeding week to notify of any changes in Nominated kW. The
Nominated kW may be raised or lowered each week without restriction any time before the third minimum
Program Event is called. After the third Program Event is called, the Nominated kW may still be raised or
lowered, but may not exceed the highest Nominated kW prior to the third Program Event being called.

INCENTIVE STRUCTURE

Incentive payments will be determined based on a Fixed Capacity Payment, a Variable Energy
Payment, and any applicable Nominated kW Incentive Adjustment. Both the Fixed Capacity and Variable
Energy Payments will be paid by check or bill credit no more than 45 days after the Program Season
concludes on September 15th.
Idaho Power Company Second Revised Sheet No. 82-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

INCENTIVE STRUCTURE (Continued)

When a Program Event is called and a Participant exceeds the Nominated kW, the Fixed Capacity
Payment will be capped at 20 percent above original Nominated kW.

Participants are expected to reduce their load by the Nominated kW during each hour of each
Program Event for the duration of the event. Each time a Participant fails to achieve a load reduction of
up to the Nominated kW during a Program Event, a Nominated kW Incentive Adjustment will apply.

For Program Events, the Nominated kW Incentive Adjustment will be $2.00 per kW for each hour
the Nominated kW is not achieved during that interval. The total Nominated kW Incentive Adjustments
will not exceed the total incentive amount for the Program Season.

TERMS OF PARTICIPATION

Participants must submit a Program Application initially, but are automatically re-enrolled each
year thereafter. Participants will be notified prior to each Program Season of the automatic re-enrollment.
This Program Application must include the Facility Site(s) they wish to enroll and the initial Nominated
kW for each Facility Site. If a Participant requests the Aggregated Option they must specify this on the
Program Application.

1. A Participant may terminate their participation in the Program at any time during or before
the Program Season by notifying the Company in writing.

2. Upon terminating participation of a Facility Site, the Participant’s incentive payment shall
be prorated for the number of Business Days of participation in the Program. The
Participant may not re-enroll the Facility Site into the Program until the following calendar
year.

SPECIAL CONDITIONS

The provisions of this Program do not apply for any time period that the Company requests a load
reduction during a system emergency in accordance with NERC standards, Idaho Power’s Rule J, or any
other time that a Customer’s service is interrupted by events outside the control of the Company. The
provisions of this Program will not affect the calculation or rate of the regular Service, Energy, or Demand
Charges associated with a Participant’s standard service schedule.
Fixed Capacity Payment Rate*
(*to be prorated for partial weeks) Variable Energy Payment Rate*
(*does not apply to first four Program Events)

$3.25 per Weekly Effective kW Reduction

$0.20 per kWh

LEGISLATIVE FORMAT
Idaho Power Company SeventhEighth Revised Sheet No. 23-1
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 30, 2015
Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)

PURPOSE

The Irrigation Peak Rewards Program (the Program) is an optional, supplemental service that
permits participating agricultural irrigation Customers taking service under Schedule 24 to allow the
Company to turn off specific irrigation pumps with the use of one or more Load Control Devices. In
exchange for allowing the Company to turn off specified irrigation pumps, participating Customers will
receive a financial incentive for load reductions during the calendar months of June, July, and August,
and September for each metered service point (Metered Service Point) enrolled in the Program.

AVAILABILITY

Service under this schedule is available on an optional basis to Customers with a Metered Service
Point or Points receiving service under Schedule 24 where the Metered Service Point serves a water
pumping or water delivery system used to irrigate agricultural crops or pasturage. The Program is only
available to Customers that have an existing dispatchable Load Control Device installed on their
equipment and existing participants under the Manual Dispatch Option.

The Company shall have the right to select and reject Program participants at its sole discretion
based on criteria the Company considers necessary to ensure the effective operation of the Program.
Selection criteria may include, but will not be limited to, Billing Demand, location, pump horsepower,
pumping system configuration, or electric system configuration. Past participation does not ensure
selection into the Program in future years. Participation may be limited based upon the availability of
Program equipment and funding.

Each eligible Customer who chooses to take service under this optional schedule is required to
enter into a Uniform Irrigation Peak Rewards Service Application/Agreement (Agreement) with the
Company prior to being served under this schedule. The Agreement will grant the Company or its
representative permission, on reasonable notice, to enter the Customer’s property to maintain one or
more Load Control Devices on the electrical panel servicing the irrigation equipment associated with the
Metered Service Points that are enrolled in this Program and to allow the Company or its representative
reasonable access to the Load Control Device(s). By entering into the Agreement, each Customer also
agrees to not increase for the sole purpose of participating in the Program the capacity, horsepower (HP)
or size of the irrigation system served by the Company.

PROGRAM DESCRIPTION

Service under this optional, supplementary Program permits the Company to turn off specified
irrigation pumps for a limited number of hours during the period of June 15 through August September
15 (Program Season). The Company will utilize dispatchable Load Control Devices to turn off specific
irrigation pumps during Load Control Events. In limited applications, a select group of eligible Customers
will be permitted to manually interrupt electric service to participating irrigation pumps during Load Control
Events (See Manual Dispatch Option). In exchange for allowing the Company to interrupt service to
specified irrigation pumps, participating Customers will receive a financial incentive for usage that occurs
during the calendar months of June, July, and August, and September for each Metered Service Point
enrolled in the Program.

DEFINITIONS
Idaho Power Company SeventhEighth Revised Sheet No. 23-1
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 30, 2015
Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

Notification of Program Acceptance. An interested Customer must sign and return to the
Company an Agreement specifying the Metered Service Point(s) to be included in the Program. If a
Customer is selected for participation in the Program, a notification of acceptance into the Program will

Idaho Power Company SeventhEighth Revised Sheet No. 23-2
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-2
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)
DEFINITIONS (Continued)
DEFINITIONS

Notification of Program Acceptance. An interested Customer must sign and return to the Company an
Agreement specifying the Metered Service Point(s) to be included in the Program. If a Customer is
selected for participation in the Program, a notification of acceptance into the Program will be mailed to
participants, which will include a listing of the Metered Service Point(s) that have been enrolled.

Load Control Device. Load Control Device refers to any technology, device, or system utilized
under the Program to enable the Company to initiate the Load Control Event.

Load Control Event. Refers to an event under the Program where the Company requests or calls
for interruption of specific irrigation pumps either manually or with the use of one or more Load Control
Devices.

Program Season. The Program Season is the period June 15 through AugustSeptember 15 of
each year.

Program kW. The Program kW is the demand amount, as measured at the Customer’s meter in
kilowatts (kW) associated withduring the applicable billing periodProgram Season, that is multiplied by
the applicable incentive amount to determine the Demand Credit under the Automatic Dispatcheach
Interruption Option. Under the Manual Dispatch Interruption Option, the Program kW will be based upon
the maximum measured interval kW during the 24-hour period preceding 8:00 A.M. MDT the day of the
announcement of a Load Control Event, minus the average interval kW during an event.

Nominated Demand. Nominated Demand is the amount of demand that participants under the
Manual Dispatch Option must declare as availableplanned to be available for dispatch during Load
Control Events.

Program kWh. The Program kWh is the energy amount, as measured at the Customer’s meter
in kilowatt-hours (kWh) associated with the applicable billing period, during the Program Season, that is
multiplied by the applicable incentive amount to determine the Energy Credit under each Interruption
Option.

Variable Program kWh. The Variable Program kWh is the demand amount for the associated
billing period, as measured at the Customer’s meter in kilowatts (kW) multiplied by the hours of
interruption for the Metered Service Point for each Load Control Eventduring the Program Season. The
Variable Program kWh is multiplied by the applicable variable incentive payment to determine the
Variable Energy Credit under each Interruption Option.
Variable Program kWh = meteredProgram kW x hours of interruption for each Load Control
Eventduring Program Season

Bill Credit. The Bill Credit is the sum of the Demand Credit and the Energy Credit applied to the
Customer’s monthly bills for usage that occurs during the calendar months of June, July, and August,
and September of each calendar year. This amount may be prorated for the number of days during the
months of June, July, and August, and September that fall in the Customer’s billing cycle to correspond
with the Program Season. The Bill Credit amount may be applied directly to participating Customers’
bills or provided in the form of a check.

Idaho Power Company SeventhEighth Revised Sheet No. 23-2
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-2
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16
Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Demand
Credit is calculated by multiplying the Program kW by the demand-related incentive amount for the
Interruption Option selected by the Customer. The Demand Credit will be included on the Customer’s
monthly bills for usage that occurs during the calendar months of June, July, and August, and September
of each year. This amount may be prorated for the number of days during the months of June, July, and
August, and September that fall in the Customer’s billing cycle to correspond with the Program Season.
Demand Credit = Program kW x demand-related incentive amount
Idaho Power Company SeventhEighth Revised Sheet No. 23-3
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-3
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

DEFINITIONS (Continued)

Energy Credit. The Energy Credit is an energy-based financial incentive provided in the form of
a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Energy
Credit is calculated by multiplying the Program kWh by the energy-related incentive amount for the
Interruption Option selected by the Customer. Customers identified to have an out-of-demand season
billing cycle will receive only an out-of-demand season energy credit for the applicable billing period. The
Energy Credit will be included on the Customer’s monthly bills for usage that occurs during the calendar
months of June, July, and August, and September of each year. This amount may be prorated for the
number of days during the months of June, July, and August, and September that fall in the Customer’s
billing cycle to correspond with the Program Season.
Energy Credit = Program kWh x energy-related incentive amount

Variable Energy Credit. The Variable Energy Credit is an energy-based financial incentive
provided for the Metered Service Point enrolled in the Program. The Variable Energy Credit is calculated
by multiplying Variable Program kWh by the energy-related incentive amount for the Interruption Option
selected by the Customer. The Variable Energy Credit is paid in the form of a check no later than 4570
days after the Program Season. This amount may be prorated for the number of days during the months
of June, July, and August that fall in the Customer’s billing cycle to correspond with the Program Season.
The Variable Energy Credit does not apply to the first fourthree Load Control Events.
Variable Energy Credit = Variable Program kWh x variable energy-related incentive amount

INTERRUPTION OPTIONS

Under the Interruption Options, the Company will dispatch remotely service interruptions to
specified irrigation pumps any Monday through Saturday during the Program Season between the hours
of 13:00 P.M. and 810:00 P.M. Mountain Daylight Time (MDT), excluding holidays (Standard
Interruption). Customers may elect to participate until 911:00 P.M. MDT (Extended Interruption) and will
receive a larger Variable Energy Credit. Service interruptions may last up to 4 hours per day and will not
exceed 156 hours per calendar week and 60 hours per Program Season. During each Program Season
the Company will conduct a minimum of three Load Control Events. Customers participating in the
Automatic Dispatch Option may not receive advance notification of a Load Control Event, but will be
notified after the Load Control Event begins. Customers participating in the Manual Dispatch Option will
receive advance notification at least 4 hours prior to a Load Control Event. The Company will provide
notice of a Load Control Event via the following communication technologies: telephone, e-mail and/or
text message. If prior notice of a pending Load Control Event has been sent, the Company may choose
to revoke the Load Control Event and will provide notice to Customers up to 30 minutes prior to the Load
Control Event.

Customers who elect to participate in the Program may be eligible for one of the following
Interruption Options:

INTERRUPTION OPTIONS (Continued)

Idaho Power Company SeventhEighth Revised Sheet No. 23-3
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-3
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16
Automatic Dispatch Option. A dispatchable Load Control Device will be connected to the
electrical panel(s) serving the irrigation pumps associated with the Metered Service Points
enrolled in the Program. The Load Control Device utilized under the Automatic Dispatch Option

Idaho Power Company SeventhEighth Revised Sheet No. 23-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 SixthSeventh Revised Sheet No. 23-4
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

INTERRUPTION OPTIONS (Continued)
INTERRUPTION OPTIONS (Continued)

Automatic Dispatch Option. A dispatchable Load Control Device will be connected to the
electrical panel(s) serving the irrigation pumps associated with the Metered Service Points
enrolled in the Program. The Load Control Device utilized under the Automatic Dispatch Option
will provide the Company the ability to send a signal that will interrupt operation or not allow the
associated irrigation pumps to operate during dispatched Load Control Events. This option
requires that all pumps at the Metered Service Point be controlled.

Under the Automatic Dispatch Option, the Program kW will be based upon the
monthly Billing Demand, as measured in kW, for the associated Billing Period. The Program kWh
under this option will be based upon the monthly energy usage, as measured in kWh, for the
associated Billing Period.

Customers selecting the Automatic Dispatch Option may opt-out of a Load Control
Event up to five times per season prior to or during a Load Control Event. Each time a customer
chooses to opt-out of one of the three minimum Load Control Events a fee of $5.006.25 per kW
will be assessed based upon the current Billing Period’s kW. Each time a customer chooses to
opt-out of a Load Control Event after the three minimum Load Control Events a fee of $1.00 per
kW will be assessed based upon the current Billing Period’s kW. The opt-out fee will not exceed
the total Bill Credit for the Program Season. Any opt-out fee will be applied at the end of the
Program Season or after the applicable billing cycle closes. Opt-out fees may be waived for
circumstances involving planned or unplanned outages of 3 hours or more occurring within 24
hours of a Load Control Event or a multiday outage within 72 hours of an event. At its discretion,
the Company may assess an opt-out fee should it be determined the participant overrode the
command to the dispatch device thereby allowing the pump to run during the load control event.

Manual Dispatch Option. Customers are eligible to manually control Metered Service Points
of at least 1,000 cumulative HP, or Metered Service Points that have been determined by the
Company to be limited by load control device communication technology or installation
configuration, are eligible for the Manual Dispatch Option. Under the Manual Dispatch Option,
eligible Customers have the flexibility to choose which irrigation pumps at a Metered Service Point
will be interrupted during each dispatched Load Control Event. Customers electing this option
must notify the Company of their Nominated Demand during the enrollment period prior to June
1 of each year.

Customers selecting participating in the Manual Dispatch Option are required to
provide no less than their Nominated Demand during each Load Control Event. Each time a
customer chooses to provide less than their Nominated Demand during one of the three minimum
Load Control Events, an opt-out fee of $5.006.25 per kW will be assessed on the Nominated
Demand not made available for interruption. Each time a customer chooses to provide less than
their Nominated Demand during a Load Control Event, after the three minimum Load Control
Events, an opt-out fee of $1.00 per kW will be assessed on the Nominated Demand not made
Idaho Power Company SeventhEighth Revised Sheet No. 23-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 SixthSeventh Revised Sheet No. 23-4
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16
available for interruption. The opt-out fee will not exceed the total Bill Credit for the Program
Season. Any opt-out fee will be applied at the end of the Program Season or after the applicable
billing cycle closes. Opt-out fees may be waived for circumstances involving planned or
unplanned outages of 3 hours or more occurring within 24 hours of a Load Control Event or a
multiday outage within 72 hours of an event.
Idaho Power Company SeventhEighth Revised Sheet No. 23-5
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-5
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

INTERRUPTION OPTIONS (Continued)

Under the Manual Dispatch Option, the Program kW will be based upon the
maximum measured interval demand during the 24-hour period preceding 8:00 A.M. MDT the day
of the announcement of a Load Control Event, minus the average demand during an event, as
measured in kW over applicable load profile metering intervals. This applies to each Load Control
Event initiated during a Billing Period. If there are no Load Control Events during a Billing Period
then the Program kW will be the Nominated Demand. The Program kWh under this option will be
based upon a calculated value, as measured in kWh. The Program kWh will be calculated
separately for each Billing Period by multiplying the monthly Program kW by the ratio of the
monthly energy usage to the Billing Demand for the associated Billing Period.

INCENTIVE STRUCTURE

Incentive payments under the Interruption Options will be determined based on a fixed payment
and a variable payment. The fixed portion of the incentive payment will be paid through a Bill Credit and
the variable portion will be paid by check no more than 4570 days after the end of the Program Season.
The first fourthree Load Control Events will not be subject to the Variable Energy Credit. The variable
payment will be based on the number of hours a participant’s pump is interrupted during the Program
Season and their associated Program kW after the first fourthree Load Control Events.

INSTALLATION FEES

An Installation Fee of $500 will be required for any new participating Metered Service Point with
measured horsepower of 30 or less. The Installation Fee is non-refundable except when a Customer
elects early termination and prior to the installation of a load control device at their pump location.

TERM OF AGREEMENT AND TERMINATION

The term of the Agreement, as it applies to each Metered Service Point accepted for participation,
shall commence on the date the Agreement is signed by both the Customer and the Company and shall
automatically renew on March 15 of each calendar year unless notice of termination is given by either
party to the other prior to the annual renewal date or unless otherwise terminated as follows:

Interruption Option
Fixed Incentive Payment Variable Incentive Payment

Demand Credit
($ per Program kW)
Energy Credit
($ per Program kWh)
Energy Credit ($
per Program
kWh) for Out-of-
Demand
Season Billing
Cycles
Standard
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
Extended
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
$5.0025 $0.00768 $0.021 $0.148 $0.19825
Idaho Power Company SeventhEighth Revised Sheet No. 23-5
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-5
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16
1. A Customer may terminate the participation of a Metered Service Point and avoid the Termination
Fee by notifying the Company or its representative before the Program Season.

TERM OF AGREEMENT AND TERMINATION

The term of the Agreement, as it applies to each Metered Service Point accepted for participation,
shall commence on the date the Agreement is signed by both the Customer and the Company and shall
automatically renew on March 15 of each calendar year unless notice of termination is given by either
party to the other prior to the annual renewal date or unless otherwise terminated as follows:

1. A Customer may terminate the participation of a Metered Service Point and avoid the Termination
Fee by notifying the Company or its representative before the Program Season.

Idaho Power Company SeventhEighth Revised Sheet No. 23-6
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-6
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

TERM OF AGREEMENT AND TERMINATION (Continued)

2. A Customer who terminates the participation of a Metered Service Point anytime between
June 15 and AugustSeptember 15 of each calendar year shall pay the Company a Termination
Fee. This fee, which sum will be included on the Customer’s monthly bill following termination of
participation. The Customer’s Bill Credit shall be prorated for the number of days in that month
the Customer satisfactorily participated in the Program. Upon terminating participation of a
Metered Service Point under the provisions of item 2, the Customer may not re-enroll the Metered
Service Point into the Program until the following calendar year and the applicable Termination
Fee has been paid in full.

Termination Fees:

Automatic Dispatch Option: $500.00 per Metered Service Point terminated under item 2

3. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s
ability to initiate a Load Control Event at a Metered Service Point, the Agreement as it applies to
that Metered Service Point will be automatically terminated. In addition, the Customer will be
subject to each of the following:

a. The Customer will be required to reimburse the Company for the cost of
replacement or repair of the Load Control Device(s), including labor and other related
costs.

b. An applicable Termination Fee, as provided under item 2, will be applied to the
Customer’s monthly bill following the termination of participation.

c. The Company will reverse any and all Demand Credits and/or Energy Credits
applied to the Customer’s monthly bill(s) for the Metered Service Point as a result of the
Customer’s participation in the Program during the current year.

Note: A service disconnection for any reason does not terminate the Agreement.

SPECIAL CONDITIONS

The provisions of this schedule do not apply for any time period that the Company utilizes a Load
Control Device installed under this Program to interrupt the Customer’s load for a system emergency in
accordance with NERC standards, Idaho Power’s Rule J, or any other time that a Customer’s service is
interrupted by events outside the control of the Company. The provisions of this schedule will not affect
the calculation or rate of the regular Service, Energy or Demand Charges associated with a Customer’s
standard service schedule.
Idaho Power Company SeventhEighth Revised Sheet No. 23-7
Cancels
I.P.U.C. No. 29, Tariff No. 101SixthSeventh Revised Sheet No. 23-7
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)

Uniform Irrigation Peak Rewards Service
Application/Agreement

THIS AGREEMENT Made this ____ day of _________________________________, ______
between __________________________________________________________ hereinafter called
Customer, whose billing address is _____________________________________________________,
and IDAHO POWER COMPANY, a corporation with its principal office located at 1221 West Idaho Street,
Boise, Idaho, hereinafter called Company. This Agreement shall automatically renew on March 15 of
each calendar year unless notice of termination is given by either party to the other prior to the annual
renewal date. This Agreement is for the Metered Service Point(s) identified on the attached worksheet
(Worksheet):

The Customer designates the following person as the Customer’s authorized contact:

Authorized Contact: _________________________________________________________________
Phone: ______________________________________ Cell Phone: __________________________
Fax: _____________________________________________________________________________
Email: ____________________________________________________________________________

NOW, THEREFORE, The Parties agree as follows:

1. The Uniform Irrigation Peak Rewards Service Application/Agreement must be signed by the
Customer and the Customer must be the person who is responsible for paying bills for retail
electric service provided by the Company at the Metered Service Point(s) identified on the
Worksheet.

2. The Customer understands that the information concerning the Metered Service Point(s) on the
Worksheet is based on the best information currently available to the Company. The Bill Credit
amounts are estimates based on the previous year’s billing history for the Metered Service
Point(s) specified on the Worksheet. Customers without sufficient billing history will be provided
an estimated Bill Credit based on the stated cumulative horsepower at the Metered Service Point.
The Bill Credit estimates are provided for illustration purposes. The Customer agrees to specify
which Metered Service Point(s) listed on the Worksheet the Customer wishes to enroll in the
Program and the Interruption Option selected for each specified Metered Service Point. For
Metered Service Points enrolled in the Manual Dispatch Option the Customer must notify the
Company of Nominated Demand amounts by June 1 of each year.

Idaho Power Company SixthSeventh Revised Sheet No. 23-8
Cancels
I.P.U.C. No. 29, Tariff No. 101 FifthSixth Revised Sheet No. 23-8
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 30, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – February 15, 2016February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)
(Continued)
Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

3. From time to time during the term of this Agreement and with prior reasonable notice from the
Company, the Customer shall permit the Company or its representative to enter the Customer’s
property on which the enrolled Metered Service Point(s) are located to permit the Company or its
representative to install, service, maintain and/or remove Load Control Device(s) on the electrical
panel that services the Customer’s irrigation pumps. The Load Control Device(s) may remain in
place on the Customer’s property upon termination of the Agreement unless the Customer
specifically requests removal.

4. The Customer understands and acknowledges that by participating in the Program, the Company
shall, at its sole discretion, have the ability to interrupt the specified irrigation pumps at the
Metered Service Point(s) enrolled in the Program according to the provisions of the Interruption
Option selected. The Company retains the sole right to determine the criteria under which a Load
Control Event is scheduled for each Metered Service Point. The Customer also understands and
acknowledges that if a Metered Service Point provides electricity to more than one irrigation
pump, each pump will be scheduled for service interruption simultaneously, excluding Metered
Service Points participating in the Program under the Manual Dispatch Option.

5. For the Customer’s satisfactory participation in the Program, the Company agrees to pay the
Customer the Demand Credit and/or Energy Credit corresponding to the Interruption Option
selected by the Customer. The Bill Credit included on the Worksheet is based upon the billing
history for the Metered Service Point(s) specified on the Worksheet, for the months of June, July,
and August, and September of the prior year. The Bill Credit will be paid in the form of a credit
on the Customer’s monthly bill or provided in the form of a check. The Demand Credit may be
prorated for the months of June, July, and August, and September depending on the Customer’s
billing cycle.

Metered Service Points participating under the Manual Dispatch Option, will receive a Bill Credit
from the Company within 30 days of billing due to the extensive data analysis required to process
interval metering data. Any applicable Variable Energy Credits will be paid by check no more than
70 days after the end of the Program Season.

6. If the Customer terminates this Agreement anytime between June 15 and SeptemberAugust 15
of the current calendar year while the Metered Service Point(s) are still connected for service the
Customer may not re-enroll that Metered Service Point into the Program until the following
calendar year and the applicable Termination Fee has been paid in full.

Idaho Power Company SecondThird Revised Sheet No. 81-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 81-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32923 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022January 1, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)

PURPOSE

The Residential Air Conditioner Cycling Program is an optional, supplemental service that
permits participating residential Customers an opportunity to voluntarily allow the Company to cycle
their central air conditioners with the use of a direct load control Device installed at their residence.
Customers will receive a monetary incentive for successfully participating in the Program during the Air
Conditioning Season.

DEFINITIONS

AC Cycling is the effect of the Company sending a signal to a Device installed at the Customer’s
residence and instructing it to cycle the Central Air Conditioning compressor for a specified length of
time.
Air Conditioning Season is the period that commences on June 15 and continues through
August September 15 of each calendar year.

Central Air Conditioning is a home cooling system that is controlled by one or more centrally
located thermostats that controls one or more refrigerated air-cooling units located outside the
Customer’s residence.

Cycling Event is a period during which the Company sends a signal to the Device installed at
the Customer’s residence, which instructs the Device to begin AC Cycling.

Device is a direct load control device installed at a Customer’s residence that enables the
Company to conduct AC Cycling.

Notification refers to the Customer’s indication of intent to initiate or terminate participation in the
Program by either contacting the Company’s Customer Service Center, providing written notice or
submitting an electronic Application via the Company’s website.

Opt Out is the term used to describe the two times each Air Conditioning Season in which the
Customer may choose to temporarily not participate in AC Cycling by providing advanced Notification to
the Company.

Program Operation Area describes the area in which the Program will be offered to Customers
and is comprised of the Company’s service territory within the State of Idaho where the infrastructure
required to support AC Cycling has been installed and is operational.

Idaho Power Company Second Third Revised Sheet No. 81-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Second Revised Sheet No. 81-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32923 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 15, 2022January 1, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)
(Continued)

PROGRAM DESCRIPTION

1. At the Company’s expense, the Company or its representative will install a Device at the
Customer’s residence.

2. A financial incentive of $5.00 per month for each of the fourthree months of June, July,
and August, and September will be paid to each Customer who successfully participates in the
Program. This incentive will be paid in the form of a credit on the Customer’s monthly bill for each
month that the Customer successfully participates in the Program, beginning with the July bill and
ending with the OctoberSeptember bill. Incentive payments are limited to one controlled Central Air
Conditioning unit per metered service point. Customers who have more than one Central Air
Conditioning unit at a metered service point may participate in the Program. A Device must be installed
at each Central Air Conditioning unit. However, no additional incentive will be paid.

3. The Company will send a signal to the Device to initiate a Cycling Event. A Cycling
Event may be up to four hours per day on any weekday during the Air Conditioning Season, excluding
holidays. A Cycling Event may occur over a continuous 4-hour period or may be segmented
throughout the day at the Company’s discretion in order to optimize available resources. Cycling
Events may occur up to 156 hours each week and will not exceed a total of 60 hours per Air
Conditioning Season. During each Air Conditioning Season, the Company will conduct at least three
Cycling Events. Mass memory meters or end-use meters may be installed on some Customers’
residences or Central Air Conditioning units for program evaluation purposes. The residences or
Central Air Conditioning units selected for installation of the meter shall be at the Company’s sole
discretion.

SPECIAL CONDITIONS

The Company is not responsible for any consequential, incidental, punitive, exemplary or
indirect damage to the participating Customer or third parties that results from AC Cycling, from the
Customer’s participation in the Program, or of Customer’s efforts to reduce peak energy use while
participating in the Program.

The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Device and any and all implied warranties are disclaimed.

The Company shall have the right to select the AC Cycling schedule and the percentage of
Customers’ Central Air Conditioning systems to cycle at any one time, up to 100%, at its sole
discretion.

The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer’s load for a system emergency in accordance with NERC standards, Idaho Power’s Rule J,
or any other time that a Customer’s service is interrupted by events outside the control of the Company.
The provisions of this schedule will not affect the calculation or rate of the regular Service or Energy
Charges associated with a Customer’s standard service schedule.
Idaho Power Company FirstSecond Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued December 16, 2016 per Order No.
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2017February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 16-07

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

PURPOSE

The Flex Peak Program (the Program) is a voluntary program that motivates Participants to
reduce their load during Company initiated demand response events. A participating Customer will be
eligible to receive a financial incentive in exchange for being available to reduce their load during the
calendar months of June, July, and August, and September.

AVAILABILITY

The Program is available to Commercial and Industrial Customers receiving service under
Schedules 9, 19, or a Special Contract Schedule.

The Company shall have the right to accept Participants at its sole discretion based on criteria
the Company considers necessary to ensure the effective operation of the Program. Selection criteria
may include, but will not be limited to, total Program capacity, a Facility Site location, or amount of
capacity provided at a Facility Site.

To participate in the Program, a Customer must sign and return the Program Application and
worksheet provided by the Company specifying the Facility Site(s) to be enrolled in the Program. To
enroll in the Program, Customers must be capable of providing a minimum load reduction of 20 kW per
Facility Site or an aggregate reduction of 35 kW if participating under the Aggregated Option. If a Facility
Site is accepted for participation in the Program, a Notification of Program Acceptance will be mailed to
the Participant within 10 business days of the Company receiving the Program Application. Notification
of Program Acceptance will include a listing of the Facility Sites that have been enrolled.

PROGRAM DESCRIPTION

The Company will initiate Program Events for a maximum of 60 hours during June, July, and
August, and September. dDuring those Program Events, Participants will be expected to reduce load at
their Facility Site(s). Participants will be eligible to receive a financial incentive in exchange for their
reduction in load.

DEFINITIONS

Actual kW Reduction. The kilowatt (kW) reduction during a Program Event, which is the difference
between a Participant’s hourly average kW measured at the Facility Site’s meter and the corresponding
hour of the Adjusted Baseline kW.

Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment
amount.

Aggregated Option. Multiple Facility Sites belonging to a single Participant that are grouped
together per the customer’s request with a single Nominated kW for participation in the Program. Under
this option, the Company will sum the individual performance data from each enrolled Facility Site before
calculating any incentive amounts.
Idaho Power Company FirstSecond Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued December 16, 2016 per Order No.
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2017February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 16-07

Idaho Power Company First Revised Sheet No. 82-2
Cancels

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33292 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 7, 2015February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Business Days. Any day Monday through Friday, excluding holidays. For the purposes of this
Program, Independence Day and Labor Day are is the only holidays during the Program Season. If
Independence Day falls on Saturday, the preceding Friday will be designated the holiday. If
Independence Day falls on Sunday, the following Monday will be designated the holiday.

Capacity Payment. The Weekly Effective kW Reduction multiplied by the Capacity Payment rate
(as described in the Incentive Structure section).

“Day of” Load Adjustment. The difference between the average Original Baseline kW and the
average actual metered kW during the two hours prior to the Participant receiving notification of the
Participant receiving notification of an event. Scalar values will be calculated by dividing the Original
Baseline kW for each Program Event hour by the Baseline kW of the hour preceding the event notification
time. This adjustment is used to account for a customer using more or less load than their Original
Baseline kW predicts on the day of the Program Event. “Day of” Load Adjustment will be applied to the
Original Baseline kW for each Facility Site for each interval during the Program Event time when a
Program Event is called. This adjustment will be capped at 20 percent below or above the Original
Baseline kW. The scalars are multiplied by the actual event day kW for the hour preceding the event
notification time to create the Adjusted Baseline kW from which load reduction is measured. The Adjusted
Baseline kW for each hour cannot exceed the maximum kW amount for any hour from the Highest Energy
Use Days or the hours during the event day prior to event notification.

Energy Payment. An energy-based financial incentive provided to the Participant. The payment
is calculated by multiplying Variable Program kWh by the Energy Payment Rate (as described in the
Incentive Structure section). The Energy Payment does not apply to the first three Program Events.

Event Availability Time. Between 23:00 p.m. and 810:00 p.m. Mountain Daylight Time (MDT)
each Business Day.

Facility Site(s). All or any part of a Participant’s facility or equipment that is metered from a single
service location that a Participant has enrolled in the Program. For those Participants who have enrolled
under the Aggregated Option, Facility Site will refer to the combination of individual Facility Sites selected
for inclusion under the Aggregated Option.

Fixed Capacity Payment. The Weekly Effective kW Reduction multiplied by the Fixed Capacity
Payment rate (as described in the Incentive Structure section). Participants are paid based on the
average event kilowatt reduction.

Highest Energy Usage Days. The three days out of the immediate past 10 non-event Business
Days that have the highest average sum total kW as measured across the Event Availability Time.

Hours of Event. The timeframe when the Program Event is called and Nominated kW is expected
to be reduced. The Hours of Event will not be less than two hours and will not exceed four hours.

Idaho Power Company First Revised Sheet No. 82-2
Cancels

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33292 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 7, 2015February 15, 2022 1221 West Idaho Street, Boise, Idaho
Nominated kW. The amount of load expressed in kW that a Facility Site commits to reduce during
a Program Event.

Nominated kW Incentive Adjustment. An adjustment made when a Facility Site does not achieve
its Nominated kW for a given hour during a Program Event. The adjustment will be made for each hour
the Nominated kW is not achieved. The total Nominated kW Incentive Adjustment will not exceed the
total incentive amount for the Program Season (as described in the Incentive Structure section).

Idaho Power Company First Revised Sheet No. 82-3
Cancels

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33292 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 7, 2015February 15, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Nominated kW Incentive Adjustment. An adjustment made when a Facility Site does not achieve
its Nominated kW for a given hour during a Program Event. The adjustment will be made for each hour
the Nominated kW is not achieved. The total Nominated kW Incentive Adjustment will not exceed the
total incentive amount for the Program Season (as described in the Incentive Structure section).

Notification of Program Acceptance. Written confirmation from the Company to the Participant.
The Notification of Program Acceptance will confirm each Facility Site enrolled in the Program, as well
as the Nominated kW amount for each Facility Site.

Original Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days
during the Event Availability Time, calculated for each Facility Site for each hour.

The following table provides an example of the calculation of the Original Baseline kW between hours of
32:00 p.m. and 108:00 p.m. using the (3) Highest Energy Usage Days of 5, 7, and 9.

Day 23‐43 PM 
(kW) 
34‐45 PM 
(kW) 
45‐56 PM  
(kW) 
56‐67 PM 
(kW) 
67‐78 PM 
(kW) 
78‐89 PM 
(kW) 

9‐10 PM 
(kW) 
Average 
UsageSum 
Total (kW) 
 1 3000 3100 3000 3200 3000 3200 3150 308321650  
 2 3200 3100 3200 3200 3100 3300 3300 318322400  
 3 3100 3200 3100 3100 3200 3100 3200 313322000  
 4 3250 3400 3300 3400 3300 3400 3200 334223250  
 5 3300 3400 3300 3400 3400 3500 3400 338323700  
 6 3100 3000 3200 3100 3100 3200 3300 311722000  
 7 3400 3300 3400 3300 3400 3300 3200 335023300  
 8 3300 3200 3300 3300 3300 3200 3100 326722700  
 9 3400 3500 3350 3400 3500 3400 3350 342523900  
 10 3250 3300 3300 3200 3200 3200 3300 324222750  

Original 
Baseline 
(kW) 3367 3400 3350 3367 3433 3400 

3317    
Participant. Any Customer who has a Facility Site that has been accepted into the Program.

Program Application. Written form submitted by a Customer who requests to enroll a Facility
Site in the Program.

Program Event. A time period when the Company requests or calls for reduction of the Nominated
kW.

Program Season. June 15th through September 15th of each year.
Idaho Power Company First Revised Sheet No. 82-3
Cancels

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33292 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 7, 2015February 15, 2022 1221 West Idaho Street, Boise, Idaho

Program Week. Monday through Friday.

Idaho Power Company First Second Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original First Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued December 16, 2016 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2017February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 16-07

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

Program Event. A time period when the Company requests or calls for reduction of the Nominated
kW.

Program Season. June 15th through August 15th of each year.

Program Week. Monday through Friday.

Variable Program kWh. The kWh savings amount calculated by multiplying the Actual kW
Reduction by each of the Hours of Event for the Facility Site during each Program Event beyond the first
threefour Program Events.

Variable Energy Payment. An energy-based financial incentive provided to the Participant. The
payment is calculated by multiplying the Variable Program kWh by the Variable Energy Payment Rate
(as described in the Incentive Structure section). The Variable Energy Payment does not apply to the
first four Program Events.

Weekly Effective kW Reduction. The average of the Actual kW Reduction for all events in a
Program Week or in the absence of a Program Event, the Weekly Effective kW Reduction will equal the
Nominated kW for that Program Week.

PROGRAM EVENTS

The Company will dispatch Program Events on Business Days during the Program Season
between the hours of 32:00 p.m. and 108:00 p.m. MDT. Program Events will last between two to four
hours per day and will not exceed 156 hours per calendar week and 60 hours per Program Season.
During each Program Season the Company will conduct a minimum of three Program Events.
Participating Customers will receive advance notification on or about fourtwo hours prior to the Program
Event. The Company will provide notice of a Program Event via the following communication
technologies: telephone, text message, and e-mail to the designated contact(s) submitted by the
Participant in the Program Application. If prior notice of a pending Program Event has been sent, the
Company may choose to revoke the Program Event initiation and will provide notice to Participants no
less than 30 minutes prior to the Program Event.

REQUIREMENTS OF PARTICIPATING FACILITIES

Participants will have the flexibility to choose what equipment will be used to reduce the
Nominated kW during each Program Event. Participants must notify the Company of their Nominated
kW via the Program Application. Once the Program Season begins, the Participant must submit the
nomination change request form online (located at www.idahopower.com/flexpeak) via email by
Thursday at 10:00 a.m. MDT of the proceeding week to notify of any changes in Nominated kW. The
Nominated kW may be raised or lowered each week without restriction any time before the third
mandatory minimum Program Event is called. After the third Program Event is called, the Nominated kW
may still be raised or lowered, but may not exceed the highest Nominated kW prior to the third Program
Event being called.

INCENTIVE STRUCTURE
Idaho Power Company First Second Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original First Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued December 16, 2016 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2017February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 16-07

Incentive payments will be determined based on a Fixed Capacity Payment, an Variable Energy
Payment, and any applicable Nominated kW Incentive Adjustment. Both the Fixed Capacity and Variable
Energy Payments will be paid by check or bill credit no more than 3045 days after the Program Season
concludes on AugustSeptember 15th.
Idaho Power Company First Second Revised Sheet No. 82-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original First Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued December 16, 2016per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2017February 15, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 16-07

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

INCENTIVE STRUCTURE (Continued)

When a Program Event is called and a Participant exceeds the Nominated kW, the Fixed Capacity
Payment will be capped at 20 percent above original Nominated kW.

Participants are expected to reduce their load by the Nominated kW during each hour of each
Program Event for the duration of the event. Each time a Participant fails to achieve a load reduction of
up to the Nominated kW during a Program Event, a Nominated kW Incentive Adjustment will apply.

For the first three Program Events, the Nominated kW Incentive Adjustment will be $2.00 per kW
for each hour the Nominated kW is not achieved during that interval. After the first three Program Events,
the Nominated kW Incentive Adjustment will be $0.25 per kW for each hour the Nominated kW is not
achieved during that interval.

The total Nominated kW Incentive Adjustments will not exceed the total incentive amount for the
Program Season.

TERMS OF PARTICIPATION

Participants must submit a Program Application initially, but are automatically re-enrolled each
year thereafter. Participants will be notified prior to each Program Season of the automatic re-enrollment.
This Program Application must include the Facility Site(s) they wish to enroll and the initial Nominated
kW for each Facility Site. If a Participant requests the Aggregated Option they must specify this on the
Program Application.

1. A Participant may terminate their participation in the Program at any time during or before
the Program Season by notifying the Company in writing.

2. Upon terminating participation of a Facility Site, the Participant’s incentive payment shall
be prorated for the number of Business Days of participation in the Program. The
Participant may not re-enroll the Facility Site into the Program until the following calendar
year.

SPECIAL CONDITIONS

The provisions of this Program do not apply for any time period that the Company requests a load
reduction during a system emergency in accordance with NERC standards, Idaho Power’s Rule J, or any
other time that a Participant’sCustomer’s service is interrupted by events outside the control of the
Company. The provisions of this Program will not affect the calculation or rate of the regular Service,
Energy, or Demand Charges associated with a Participant’s standard service schedule.
Fixed Capacity Payment Rate*
(*to be prorated for partial weeks) Variable Energy Payment Rate*
(*does not apply to first threefour Program Events)

$3.25 per Weekly Effective kW Reduction

$0.1620 per kWh