HomeMy WebLinkAbout20231002Application.pdf
MEGAN GOICOECHEA ALLEN
Corporate Counsel
mgoicoecheaallen@idahopower.com
October 2, 2023
Jan Noriyuki, Secretary
Idaho Public Utilities Commission
11331 W. Chinden Boulevard
Building 8, Suite 201-A
Boise, Idaho 83714
Re: Case No. IPC-E-23-24
Application for Modifications to the Company’s Commercial & Industrial
Demand Response Program, Schedule 82
Dear Ms. Noriyuki:
Attached for electronic filing is Idaho Power Company’s Application in the above-
entitled matter.
If you have any questions about the attached documents, please do not hesitate
to contact me.
Sincerely,
Megan Goicoechea Allen
MGA:cd
Enclosures
RECEIVED
Monday, October 2, 2023 3:47:16 PM
IDAHO PUBLIC
UTILITIES COMMISSION
APPLICATION - 1
MEGAN GOICOECHEA ALLEN (ISB No. 7623)
LISA D. NORDSTROM (ISB No. 5733)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: (208) 388-2664
Facsimile: (208) 388-6936
mgoicoecheaallen@idahopower.com
lnordstrom@idahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR
MODIFICATIONS TO THE COMPANY’S
COMMERCIAL & INDUSTRIAL DEMAND
RESPONSE PROGRAM, SCHEDULE 82
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CASE NO. IPC-E-23-24
APPLICATION
Idaho Power ("Idaho Power" or "Company") respectfully applies to the Idaho
Public Utilities Commission (“Commission”) pursuant to Idaho Code §§ 61-503 and -
507 and Commission Rule of Procedure1 52, for authority to modify Schedule 82, Flex
Peak Program, of Idaho Power’s I.P.U.C No. 29 Tariff No. 101 (“Schedule 82”). The Flex
Peak Program (“Flex Peak” or “Program”) is the Company’s Commercial & Industrial
(“C&I”) demand response (“DR”) program used to reduce summer electricity demand
during times of system need. As more fully set forth below, in this application, Idaho Power
proposes to (1) modify the incentive payment structure, (2) add a Performance Waiver
1 Hereinafter cited as RP.
APPLICATION - 2
for customers participating in the Automatic Dispatch Option when a Load Control Device
fails, (3) adjust the “Day of” Load Adjustment definition, and (4) implement an advance
notification option for customers that participate with 3 megawatts (“MW”) or more of
nominated load reduction. Each of the proposed changes are intended to incentivize
customers to participate throughout the entire DR season, facilitate increased and/or
retain participation, and ultimately provide additional cost-effective capacity that can
be dispatched to meet system needs.
In support of this Application, Idaho Power represents as follows:
I. BACKGROUND
1. Idaho Power is a public utility supplying retail electric service to more than
610,000 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 in its Oregon service area.
2. Purpose of DR. To minimize or delay the need for new supply-side
resources, the Company’s DR programs are designed to be available to meet potential
system capacity deficits during high-risk time periods 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 acquiring a supply-side resource that would only be
necessary for a small number of hours.
3. DR Programs Offered. Idaho Power’s DR portfolio has three optional
programs with one available to each of the three major customer segments. These
APPLICATION - 3
programs represent approximately 8 percent of Idaho Power’s system peak and comprise
one of the largest utility DR portfolios in the nation proportionate to peak demand.
The residential Air Conditioner (“A/C”) Cool Credit Program (Schedule 81)
was started as a pilot in 2002 and was fully implemented in 2003. Customers’ A/C
units, or heat pumps, are controlled using Load Control Devices that communicate
via powerline carrier, and the A/C units are cycled by the Company during Load
Control Events to reduce load.
The Commercial & Industrial Flex Peak Program (Schedule 82) 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”) can either manually reduce their
nominated load when the Company calls Load Control Events or use Load Control
Devices to automatically reduce their nominated load.
The Irrigation Peak Rewards Program (Schedule 23) 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 to turn off irrigation pumps when the
Company calls Load Control Events.
4. 2021 DR Program Modifications. In Case No. IPC-E-21-32, the Company
proposed to modify all three of its DR programs to better meet system capacity needs
through program parameter updates and to supersede the 2013 Settlement Agreement
that had several program restrictions which the Company was operating the DR programs
APPLICATION - 4
under.2 The Commission approved the modifications in Order No. 35336,3 and the 2022
DR season was the first season that the DR programs operated with the updated
parameters.
5. 2022 Flex Peak Automatic Dispatch Option. On September 15, 2022, Idaho
Power requested to add a voluntary Automatic Dispatch Option to the Flex Peak Program
in Case No. IPC-E-22-24, similar to that of the A/C Cool Credit and Irrigation Peak
Rewards programs. Like the other DR programs, the option involves installing a Load
Control Device on-site either directly on the participating customer’s equipment,
connected to a customer’s energy management or building management system, or
possibly both. When a DR Load Control Event is called, the Company sends a signal to
the device(s) at the start of the event to trigger load reduction protocols at the customer’s
facilities. The purpose of adding the Automatic Dispatch Option was to make it easier for
customers to participate and increase Program capacity as short-term capacity deficits
were identified starting in 2023 in the Company’s 2021 Integrated Resource Plan (“IRP”).
The proposal did not impact the availability of the Manual Dispatch Option, and current
and potential customers are still able to participate in the Flex Peak Program manually if
preferred. The Commission approved the Company’s proposal in Order No. 35677 on
February 3, 2023, and the Company had one customer sign up for the Automatic Dispatch
Option ahead of the 2023 DR season. Idaho Power was also able to expand its own
participation in the Flex Peak Program by utilizing a Load Control Device to control
2 See 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).
3 In the Matter of Idaho Power Company’s Application for Approval to Modify its Demand Response
Programs, Case No. IPC-E-21-32, Order No. 35336 (Mar. 4, 2022).
APPLICATION - 5
multiple facilities during Load Control Events.
6. Flex Peak Program Capacity. As described above, certain parameters of
the Flex Peak Program were modified in Case Nos. IPC-E-21-32 and IPC-E-22-24 with
the changes going into effect ahead of the 2022 and 2023 DR seasons, respectively. It is
not uncommon for the Flex Peak Program to gain or lose a few participants each year,
and at the end of 2022, there were 159 participating sites and 30 MW enrolled on Idaho
Power’s system as compared to 139 sites and 36 MW enrolled at the end of 2021. 4 At
the start of the 2023 DR season, 271 participating sites were enrolled with approximately
40 MW of capacity. Idaho Power looks to increase participation/capacity with the
proposed Program updates presented in this case.
7. 2023 Flex Peak Season Performance. The Program’s results are reported
annually in a program-specific end-of-season report contained in Supplement 2 of the
Demand-Side Management (“DSM”) Annual Report. The end-of-season report contains
load reduction performance by event, realization rates, participant counts, etc. During the
Program’s 2023 season, the Company called three (3) Flex Peak DR events with an
estimated actual maximum load reduction of 35 MW. The full 2023 Program season
results will be published in March of 2024 when the Company files its 2023 DSM Annual
Report.
8. Incentive Adjustment Penalty. Currently, customers that participate in the
Flex Peak Program nominate on a weekly basis the load they are willing to reduce if a
Load Control Event is called, and their performance based on achieving their nominated
load reduction is factored into their incentive payments. Customers receive a fixed
4 DSM 2022 Annual Report at 133.
APPLICATION - 6
incentive payment of $3.25 per kW of weekly nominated load and an Incentive Adjustment
penalty of $2.00 per kW per hour is applied to the kW of nomination a customer did not
meet. For example, if a customer nominates 100 kW and their actual performance is 80
kW per hour for a 4 hour event, the customer would receive a fixed incentive of $325 (100
kW x $3.25) for that week, the Incentive Adjustment penalty of $160 (20 kW x $2.00 x 4
hours) would be subtracted from their fixed incentive payment as a result of not meeting
the nominated load. As demonstrated by the example, under the current structure, a
customer earns about 51 percent of their fixed incentive based on an actual performance
level of 80 percent of their nomination. This Incentive Adjustment penalty structure was
originally designed as a punitive measure to incentivize customers to provide reliable load
reduction based on their nominations. However, as explained in more detail below, the
current structure can eliminate a customer’s entire incentive payment even if a customer
performs well in several Load Control Events but has poor performance in others during
the DR season. Therefore, the Company proposes to replace the Incentive Adjustment
penalty structure with a tiered Fixed Capacity Payment Rate structure that pays
customers based on their average season performance when Load Control Events are
called. If a customer provides load reduction, they will be compensated for their load
reduction based on the average percentage level in which they met their nominations
during Load Control Events throughout the entire DR season.
II. TIERED FIXED CAPACITY PAYMENT RATE STRUCTURE
9. Proposed Tiered Fixed Capacity Payment Rate. Idaho Power proposes to
remove the Incentive Adjustment penalty that is currently in Schedule 82 and instead
APPLICATION - 7
modify the Fixed Capacity Payment Rate to have a tiered structure based on a customer’s
Average Season Performance Percentage, as outlined in Table 1 below.
Table 1: Tiered Fixed Capacity Payment Rate Structure
Average Season Performance
Percentage Fixed Capacity Payment Rate per kW
75% - 120% $3.25
50% - 74.99% $2.44
25% - 49.99% $1.63
Greater than 0% - 24.99% $0.81
Instead of being penalized with a $2.00 per kW per hour Incentive
Adjustment, the Company proposes to reduce the Fixed Capacity Payment Rate by the
percentage of non-performance in each tier. If a customer performs on average between
75 and 120 percent of their Nominated kW during event weeks, the customer earns the
full Fixed Capacity Payment Rate of $3.25 per kW per week. If a customer performs on
average between 50 and 74.99 percent of their Nominated kW during event weeks, the
full Fixed Capacity Payment rate of $3.25 is reduced by 25 percent to $2.44 per kW. With
the 25 to 49.99 percent tier seeing a 50 percent reduction to $1.63 per kW, and the
Greater than 0 to 24.99 percent tier seeing a reduction of the full rate by 75 percent to
$0.81 per kW per week. Whichever tier the customer falls into, that rate is then multiplied
by their Average Actual kW Reduction and the total number of weeks in the DR season
to get the final Fixed Capacity Payment (Average Actual kW Reduction x Fixed Capacity
Payment Rate x Number of Weeks in Program Season = Fixed Capacity Payment).
10. Key Objectives of the Tiered Approach. The Company believes that the
proposed tiered approach accomplishes four key objectives.
1) The tiers allow for customer performance flexibility. Most customers participate
in the Manual Dispatch Option, and based on their unique individual business
APPLICATION - 8
operations/equipment configurations, it can be difficult for a customer to meet their
exact nomination for the entirety of each event. The current Incentive Adjustment
is applied even if a customer misses their nomination by 1 kW where the proposal
pays an incentive based on a range of performance.
2) Incentivizes customers to provide load reduction throughout the entire DR
season. The current Incentive Adjustment has the ability to reduce a customer’s
total incentive to zero even if a customer performs well during some events but
poorly in others as shown in the actual customer examples included in Attachment
1. As shown in Customer Example D in Attachment 1, the customer earned nothing
even though their Average Season Performance Percentage was 64 percent.
Under the proposal, the same customer would have earned $646.50, which is
about 38 percent of the maximum incentive the customer would have earned if
they performed at the 100 percent level for the entire DR season. Under the current
structure, if a customer performs poorly early on in the season, they are no longer
incentivized to participate, because they may be unable to make up the Incentive
Adjustment penalty, or the value of the total incentive after they make up the
Incentive Adjustment penalty may be too low to make it worth their effort. The
proposal will pay an incentive for any load reduction achieved, which incentivizes
customers to perform throughout the entire DR season.
3) More accurately compensates customers based on their actual performance
when consistently performing close to their Nominated kW. As shown in Customer
Example A in Attachment 1, the customer would earn 95 percent of their maximum
incentive for an Average Season Performance Percentage of 96 percent as
APPLICATION - 9
opposed to only earning 89 percent under the current Incentive Adjustment
structure.
4) Increases customer understandability of the overall compensation structure. As
highlighted in the third key objective, it is easier for a customer to understand that
they will earn approximately 95 percent of their maximum incentive if they have a
95 percent average performance level. For customers that have Average Season
Performance Percentages in the lower tiers, below 75 percent, they will receive an
incentive for any load reduction they provide. This is an important program design
consideration, given customers that reduce load are disrupting their normal
operations. This proposal ensures customers are compensated even if the load
reduction is minimal.
III. OTHER SCHEDULE 82 UPDATES
11. Proposed Schedule 82 Changes. Attachment 2 to this Application includes
both the clean and legislative versions of the proposed Schedule 82.
12. Performance Waiver. Currently customers participating in the Automatic
Dispatch Option can have the Incentive Adjustment waived if a Load Control Device on
their equipment fails to operate. With the proposed removal of the Incentive Adjustment,
the Company proposes to replace the Incentive Adjustment Waiver with a Performance
Waiver for Automatic Dispatch Option participants where if Load Control Device fails to
operate, the Company has the ability to waive the customer’s weekly participation
requirement. That way a customer’s Fixed Capacity Payment is not affected if a device
fails when the Company calls a Load Control Event. For example, if a Participant’s Load
Control Device fails during an event, the Participant receives a Performance waiver for
APPLICATION - 10
that event, and there were a total of five Load Control Events during the Program Season,
the calculations for Average Actual kW Reduction, Average Season Performance
Percentage, Event Average Nomination, and ultimately the Fixed Capacity payment will
be based on the four Load Control Events where the Performance Waiver was not
applied.
13. “Day of” Load Adjustment Outage Update. Idaho Power proposes to update
to the “Day of” Load Adjustment definition to include a contingency when there is an
outage during a day a Load Control Event is called. The proposed language is as follows:
“The Company may adjust the Participant’s “Day of” Load Adjustment if a planned or
unplanned outage occurs during the day of a Load Control Event.” While these situations
do not occur frequently, the Company believes this provision is important and provides
the Company flexibility to accurately calculate load reduction and customer incentives if
this situation were to occur.
14. Advance Notification Option. The Company proposes to add a limited
Advance Notification Option beyond the 4-hour notification limit currently outlined in
Schedule 82 for customers that can nominate 3 MW or more of load reduction. Customers
with this amount of load have the potential to nominate a large portion, or potentially all,
of their operations during events. For customers that desire to pursue the Advance
Notification Option, the Company will evaluate these potential large customers on a case
by case basis to determine if their load profiles and/or operations would warrant advance
notification.
15. The Company is aware that event cancellations may have a negative impact
on a customer’s Program experience and it endeavors to minimize event cancellations
APPLICATION - 11
and keep customers informed. The Company continues to believe the 4-hour notice
adequately balances customers’ interest in flexibility with the operational considerations
of the Company’s Load Servicing Operations (“LSO”), who are often making decisions in
real-time about system needs, and therefore remains appropriate for the general
operation of the Program. However, the company believes having the limited ability to
offer additional Load Control Event notice to large load customers that elect and qualify
for the Advance Notification Option may incentivize current participants to nominate more
load and/or incentivize non-program participants to enroll in the Flex Peak Program.
16. Definitions and Other Schedule 82 Updates. The Company also proposes
to add the definitions of Average Actual kW Reduction, Event Performance Percentage,
Average Season Performance Percentage, Event Average Nomination, and Performance
Waiver and remove the definitions of Nominated kW Incentive Adjustment and Weekly
Effective kW Reduction as well as several other minor updates related to the proposed
changes. These new definitions and updates add clarity to the schedule associated with
the proposed changes in this filing.
IV. COST-EFFECTIVENESS & STAKEHOLDER ENGAGEMENT
17. Based on estimated 2022 DR season costs of $44 per kW per year and the
$51.425 cost-effectiveness threshold calculated in the Company’s filing in IPC-E-21-32,
Idaho Power is confident the proposed changes will not impact the cost-effectiveness of
the Flex Peak Program. None of the changes will allow customers to earn more than the
estimated maximum $44 per kW per year threshold because the maximum incentive
amounts are not changing ($3.25 per kW Fixed Capacity Payment Rate). In 2022, Idaho
5 Case No. IPC-E-21-32, Nesbitt Direct (Oct. 1, 2021) at 33.
APPLICATION - 12
Power incurred costs of $23.34 per kW per year6 for the Flex Peak Program, and this was
largely due to the Incentive Adjustment penalties customers incurred. Under the proposed
structure, costs would have been approximately $37 per kW per year. Customers would
have been compensated for their actual load reduction, and the Company believes
customers would have had an overall better experience further incentivizing them to
participate and stay in the Program.
18. Stakeholder Engagement. At the August 17, 2023 Energy Efficiency
Advisory Group (“EEAG”) meeting, the Company presented its Tiered Fixed Capacity
Rate proposal to EEAG. One EEAG member suggested applying the tiered methodology
on a per event basis rather than using the Average Actual kW Reduction when calculating
final incentive payments. Prior to finalizing its recommendation in this case, the Company
evaluated the member’s suggestion to determine the feasibility of implementing the
alternative application of the methodology. As shown in Attachment 3, and using the same
Customer Examples from Attachment 1, applying the Tiered Fixed Capacity Rate on a
per event basis does not materially change a customer’s event week Fixed Capacity
Payment for customers with consistently high levels of performance but isn’t as punitive
as the proposed calculation in the lower tiers below a 75 percent Average Season
Performance Percentage. The Company believes that using the Average Actual kW
Reduction to calculate the final incentive payment incentivizes customers to provide
reliable load reduction throughout the entire demand response season so that their
Average Season Performance Percentage, and therefore their Fixed Capacity Payment
Rate, is the highest it can possibly be. Idaho Power also believes its proposal incentivizes
6 DSM 2022 Annual Report at 135.
APPLICATION - 13
customers to participate when events are called later in the season. Beyond the
aforementioned feedback, EEAG stakeholders were supportive of the Company’s Tiered
Fixed Capacity Rate proposal.
19. Increased Participation. As part of the 2023 IRP, the Company identified
approximately 160 MW of new DR potential with 20 MW identified by 2029.7 Idaho Power
believes the Flex Peak Program updates proposed in this case will help increase
customer participation/capacity in the Program to assist in meeting the needs identified
in the IRP.
V. COMMUNICATIONS
20. Communications and service of pleadings, with reference to this
Application should be sent to the following:
Megan Goicoechea Allen Connie Aschenbrenner
Lisa Nordstrom Zack Thompson
Idaho Power Company Idaho Power Company
P.O. Box 70 P.O. Box 70
Boise, Idaho 83707 Boise, Idaho 83707
mgoicoecheaallen@idahopower.com caschenbrenner@idahopower.com
lnordstrom@idahopower.com zthompson@idahopower.com
dockets@idahopower.com
VI. MODIFIED PROCEDURE
21. Idaho Power believes that a technical hearing is not necessary to consider
the issues presented herein and respectfully requests that this Application be processed
under Modified Procedure, i.e., by written submissions rather than by hearing. RP 201, et
seq. If, however, the Commission determines that a technical hearing is required, the
Company stands ready to prepare and present its testimony in such hearing.
7 In the Matter of Idaho Power Company’s 2023 Integrated Resource Plan, Case No. IPC-E-23-23, IRP
2023 (Sept. 29, 2023) at 6.
APPLICATION - 14
VII. REQUEST FOR RELIEF
22. Idaho Power seeks to implement the updates described above for the 2024
demand response season that begins on June 15, 2024. A Commission order received
by April 15, 2024, along with a revised Schedule 82 effective coincident with a
Commission order, would best position the Company to implement and market the
proposed changes ahead of the 2024 demand response season.
23. For the reasons set forth above, Idaho Power respectfully requests that
the Commission approve the proposed updates to the Flex Peak Program and the
associated modifications to Schedule 82.
DATED at Boise, Idaho, this 2nd day of October 2023.
MEGAN GOICOECHEA ALLEN
Attorney for Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-23-24
IDAHO POWER COMPANY
ATTACHMENT 1
SEE ATTACHED EXCEL SPREADSHEET
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-23-24
IDAHO POWER COMPANY
ATTACHMENT 2
Idaho Power Company Fourth Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 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 Load Control Events or to allow the Company to send a signal
to automatically initiate a Load Control Event with the use of one or more Load Control Devices. 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, amount of capacity
provided at a Facility Site, availability of Program equipment, facility system configuration, or electric
system configuration.
To participate in the Program, a Customer must sign and return the Program
Application/Agreement and worksheet provided by the Company specifying the Facility Site(s), the
preferred Interruption Option, and the initial Nominated kW for each Facility Site 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 the Aggregated Option is requested, this should be specified on the Program Application/Agreement.
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/Agreement. Notification of Program Acceptance will include a listing of the Facility Sites that
have been enrolled.
PROGRAM DESCRIPTION
The Company will initiate Load Control Events for a maximum of 60 hours during June, July,
August, and September. During Load Control Events, Participants will be expected to reduce load at their
Facility Site(s), and load reduction may be initiated manually or automatically depending on the
Interruption Option designated for the 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 Load Control 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. In instances where a Facility Site’s actual hourly usage
exceeds the Adjusted Baseline kW, the hourly reduction will be treated as 0 kW. Actual kW Reduction
cannot exceed 120% of Nominated kW per Load Control Event.
Idaho Power Company Third Revised Sheet No. 82-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
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.
Average Actual kW Reduction. The average Actual kW Reduction for all Load Control Events in
a Program Season.
Average Season Performance Percentage. The average of the Event Performance Percentages
during the Program Season.
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 Load Control Event hour by the Original
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 Usage Days or the hours during the event day prior to
event notification. The Company may adjust the Participant’s “Day of” Load Adjustment if a planned or
unplanned outage occurs during the day of a Load Control Event.
Event Availability Time. Between 3:00 p.m. and 10:00 p.m. Mountain Daylight Time (MDT) each
Business Day.
Event Average Nomination. The average Nominated kW for a Participant during weeks Load
Control Events are called.
Event Performance Percentage. The Actual kW Reduction divided by the Nominated kW for a
Load Control Event.
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.
Idaho Power Company Third Revised Sheet No. 82-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
Fixed Capacity Payment. The Average Actual kW Reduction multiplied by the Fixed Capacity
Payment Rate determined by the Average Season Performance Percentage (as described in the
Incentive Structure section) and then multiplied by the number of weeks in a Program Season. Average
Actual kW Reduction x Fixed Capacity Payment Rate x Number of Weeks in a Program Season = Fixed
Capacity Payment.
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 Load Control 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.
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 loads either manually or with the use of one or more Load Control Devices.
Nominated kW. The amount of load expressed in kW that a Facility Site commits to reduce for a
Load Control Event. Customers can adjust their Nominated kW on a weekly basis.
Notification of Program Acceptance. Written confirmation from the Company to the Participant
based on the Program Application Agreement submitted by the Customer. The Notification of Program
Acceptance will confirm each Facility Site enrolled in the Program, the initial Nominated kW amount for
each Facility Site, and the Interruption Option 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.
Idaho Power Company Fourth Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
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.
Performance Waiver. The ability for the Company to remove a Participant’s performance during
a Load Control Event as to not affect the calculation of a Participant’s Fixed Capacity Payment.
Program Application/Agreement. Written form submitted by a Customer who requests to enroll
a Facility Site in the Program that is signed by the Customer or a duly authorized representative
certifying agreement with the Program’s terms and conditions.
Program Season. June 15th through September 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 Load Control Event beyond the
first four Load Control 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 Load Control Events.
Idaho Power Company Fourth Revised Sheet No. 82-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
LOAD CONTROL EVENTS
The Company will dispatch Load Control Events on Business Days during the Program Season
between the hours of 3:00 p.m. and 10:00 p.m. MDT. Load Control 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 Load Control Events. Participating
Customers will receive notification on or about four hours prior to the Load Control Event. The Company
will provide notice of a Load Control 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/Agreement. If prior notice of a pending Load Control Event has been sent, the Company may
choose to revoke the Load Control Event initiation and will provide notice to Participants no less than 30
minutes prior to the Load Control Event.
INTERRUPTION OPTIONS
At the Participant’s election, and subject to Company discretion, participation in the Program may
occur via one of the following Interruption Options:
Manual Dispatch Option. Customers are eligible to manually control their Facility Site(s). Under
the Manual Dispatch Option customers have the flexibility to choose which loads will be interrupted during
each dispatched Load Control Event.
Automatic Dispatch Option. A dispatchable Load Control Device, provided and installed by the
Company or its representative, will be connected to the electrical panel(s) serving the loads associated
with the Facility Site(s) enrolled in the Program. The Load Control Device utilized under the Automatic
Dispatch Option will provide the Company the ability to send a signal intended to interrupt operation of a
particular load or service during dispatched Load Control Events. In lieu of the Company or its
representative installing the Load Control Device at the Company’s expense, the Participant may elect
to hire a licensed electrician, at the Participant’s expense, to install the Load Control Device in accordance
with the National Electrical Code (“NEC”) and any Idaho Power or manufacturer specifications or
requirements.
REQUIREMENTS OF PARTICIPATING FACILITIES
Participants will have the flexibility to choose what equipment will be used to reduce the
Nominated kW during each Load Control Event. Participants must notify the Company of their Nominated
kW via the Program Application/Agreement. Once the Program Season begins, the Participant must
submit the nomination change request form online (located at www.idahopower.com/flexpeak) via email
by Monday at 10:00 a.m. MDT to notify of any changes in Nominated kW. The Nominated kW may be
raised or lowered each week without restriction.
Idaho Power Company First Revised Sheet No. 82-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
INCENTIVE STRUCTURE
Incentive payments will be determined based on a Fixed Capacity Payment, and a Variable
Energy Payment, t. 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.
The Fixed Capacity Payment Rate will be determined by the Average Season Performance
Percentage during the Program Season. For example, if a Participant’s Average Season Performance
Percentage is 65 percent, then their Fixed Capacity Payment Rate is $2.44 per kW.
Average Season Performance Percentage Fixed Capacity Payment Rate per kW*
(*to be prorated for partial weeks)
75% - 120% $3.25
50% - 74.99% $2.44
25% - 49.99% $1.63
Greater than 0% - 24.99% $0.81
At its discretion, the Company may apply a Performance Waiver should it be determined that, at
no fault of the Participant, the Load Control Device utilized for the Automatic Dispatch Option did not work
during a Load Control Event.
TERMS AND CONDITIONS
Upon acceptance into the Program, Participants agree to the provisions of this Schedule and to
the following terms and conditions:
1. Once accepted into the Program, Participants will automatically be re-enrolled each year
thereafter unless notice of termination is given by the other party.
2. Both the Company and the Participant may terminate participation in the Program
at any time by notifying the other party in writing.
3. 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. If Program
participation is terminated, the Participant may not re-enroll the Facility Site(s) into the
Program until the following calendar year.
4. The Company retains the sole right to determine the criteria under which a Load Control
Event is called and the decision of whether to call for, initiate, or cancel a Load Control
Event shall be at the Company’s sole discretion.
Variable Energy Payment Rate*
(*does not apply to first four Load Control Events)
$0.20 per kWh
Idaho Power Company First Revised Sheet No. 82-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
TERMS AND CONDITIONS (Continued)
5. 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, amount of capacity provided at a Facility Site, availability of
Program equipment, facility system configuration, or electric system configuration.
6. Participants that choose to participate in the Program under the Automatic Dispatch
Option grant the Company or its representative permission, on reasonable notice, to enter
the Customer’s enrolled Facility Site(s) to install, service, maintain, and/or remove Load
Control Device(s) on the electrical panel that services the anticipated load reduction. The
Company retains the sole right for its employees and its representatives to install or not
install Load Control Devices on the Customer’s electrical panel at the time of installation
depending on, but not limited to, safety, reliability, or other issues that may not be in the
best interest of the Company, its employees, or its representatives.
7. If there is evidence of the Participant altering, tampering, or otherwise interfering with the
Company’s ability to initiate a Load Control Event, the Customer’s participation in the
Program will be terminated, and the Customer will be required to reimburse the Company
for all costs for replacement or repair of the Load Control Device(s) or other Program
equipment, including labor and other related costs, and the Company will reverse any and
all incentive payments made during the previous twelve months as a result of the
Customer’s participation in the Program.
SPECIAL CONDITIONS
The Company is not responsible for any direct, indirect, consequential, incidental, punitive, or
exemplary damage to the Participant or third parties as a result of the Program or the Customer’s
voluntary participation in the Program.
The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Load Control Device(s) and any and all implied warranties are disclaimed.
Advance Notification Option. The Company reserves the right to use flexibility on the timing of
event notification for eligible customers nominating 3 MW or more.
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.
Idaho Power Company Third Fourth Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 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 Load Control Events or to allow the Company to send a signal
to automatically initiate a Load Control Event with the use of one or more Load Control Devices. 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, amount of capacity
provided at a Facility Site, availability of Program equipment, facility system configuration, or electric
system configuration.
To participate in the Program, a Customer must sign and return the Program
Application/Agreement and worksheet provided by the Company specifying the Facility Site(s), the
preferred Interruption Option, and the initial Nominated kW for each Facility Site 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 the Aggregated Option is requested, this should be specified on the Program Application/Agreement.
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/Agreement. Notification of Program Acceptance will include a listing of the Facility Sites that
have been enrolled.
PROGRAM DESCRIPTION
The Company will initiate Load Control Events for a maximum of 60 hours during June, July,
August, and September. During Load Control Events, Participants will be expected to reduce load at their
Facility Site(s), and load reduction may be initiated manually or automatically depending on the
Interruption Option designated for the 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 Load Control 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. In instances where a Facility Site’s actual hourly usage
exceeds the Adjusted Baseline kW, the hourly reduction will be treated as 0 kW. Actual kW Reduction
cannot exceed 120% of Nominated kW per Load Control Event.
Idaho Power Company Third Fourth Revised Sheet No. 82-1
Cancels
I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment
amount.
Idaho Power Company Second Third Revised Sheet No. 82-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Second Revised Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
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.
Average Actual kW Reduction. The average Actual kW Reduction for all Load Control Events in
a Program Season.
Average Season Performance Percentage. The average of the Event Performance Percentages
during the Program Season.
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 Load Control Event hour by the Original
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 Useage Days or the hours during the event day prior
to event notification. The Company may adjust the Participant’s “Day of” Load Adjustment if a planned or
unplanned outage occurs during the day of a Load Control Event.
Event Availability Time. Between 3:00 p.m. and 10:00 p.m. Mountain Daylight Time (MDT) each
Business Day.
Event Average Nomination. The average Nominated kW for a Participant during weeks Load
Control Events are called.
Event Performance Percentage. The Actual kW Reduction divided by the Nominated kW for a
Load Control Event.
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.
Idaho Power Company Second Third Revised Sheet No. 82-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Second Revised Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
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 Load Control 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.
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 loads either manually or with the use of one or more Load Control Devices.
Idaho Power Company Second Third Revised Sheet No. 82-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Second Revised Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
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.The Average Actual kW Reduction multiplied by the Fixed Capacity
Payment Rate determined by the Average Season Performance Percentage (as described in the
Incentive Structure section) and then multiplied by the number of weeks in a Program Season. Average
Actual kW Reduction x Fixed Capacity Payment Rate x Number of Weeks in a Program Season = Fixed
Capacity Payment.
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 Load Control 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.
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 loads either manually or with the use of one or more Load Control Devices.
Nominated kW. The amount of load expressed in kW that a Facility Site commits to reduce during
for a Load Control Event. Customers can adjust their Nominated kW on a weekly basis.
Nominated kW Incentive Adjustment. An adjustment made when a Facility Site does not achieve
its Nominated kW for a given hour during a Load Control 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
based on the Program Application Agreement submitted by the Customer. The Notification of Program
Acceptance will confirm each Facility Site enrolled in the Program, the initial Nominated kW amount for
each Facility Site, and the Interruption Option 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.
Participant. Any Customer who has a Facility Site that has been accepted into the Program.
Idaho Power Company Second Third Revised Sheet No. 82-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Second Revised Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
Program Application/Agreement. Written form submitted by a Customer who requests to enroll
a Facility Site in the Program that is signed by the Customer or a duly authorized representative
certifying agreement with the Program’s terms and conditions.
Idaho Power Company Third Fourth Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Third Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
DEFINITIONS (Continued)
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.
Performance Waiver. The ability for the Company to remove a Participant’s performance during
a Load Control Event as to not affect the calculation of a Participant’s Fixed Capacity Payment.
Program Application/Agreement. Written form submitted by a Customer who requests to enroll
a Facility Site in the Program that is signed by the Customer or a duly authorized representative
certifying agreement with the Program’s terms and conditions.
Program Season. June 15th through September 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 Load Control Event beyond the
first four Load Control 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 Load Control Events.
Idaho Power Company Third Fourth Revised Sheet No. 82-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Third Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
Weekly Effective kW Reduction. The average of the Actual kW Reduction for all events in a
Program Week or in the absence of a Load Control Event, the Weekly Effective kW Reduction will equal
the Nominated kW for that Program Week.
LOAD CONTROL EVENTS
The Company will dispatch Load Control Events on Business Days during the Program Season
between the hours of 3:00 p.m. and 10:00 p.m. MDT. Load Control 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 Load Control Events. Participating
Customers will receive advance notification on or about four hours prior to the Load Control Event. The
Company will provide notice of a Load Control 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/Agreement. If prior notice of a pending Load Control Event has been sent, the
Company may choose to revoke the Load Control Event initiation and will provide notice to Participants
no less than 30 minutes prior to the Load Control Event.
INTERRUPTION OPTIONS
At the Participant’s election, and subject to Company discretion, participation in the Program may
occur via one of the following Interruption Options:
Manual Dispatch Option. Customers are eligible to manually control their Facility Site(s). Under
the Manual Dispatch Option customers have the flexibility to choose which loads will be interrupted during
each dispatched Load Control Event.
Automatic Dispatch Option. A dispatchable Load Control Device, provided and installed by the
Company or its representative, will be connected to the electrical panel(s) serving the loads associated
with the Facility Site(s) enrolled in the Program. The Load Control Device utilized under the Automatic
Dispatch Option will provide the Company the ability to send a signal intended to interrupt operation of a
particular load or service during dispatched Load Control Events. In lieu of the Company or its
representative installing the Load Control Device at the Company’s expense, the Participant may elect
to hire a licensed electrician, at the Participant’s expense, to install the Load Control Device in accordance
Idaho Power Company Third Fourth Revised Sheet No. 82-5
Cancels
I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
INTERRUPTION OPTIONS (Continued)
LOAD CONTROL EVENTS
The Company will dispatch Load Control Events on Business Days during the Program Season
between the hours of 3:00 p.m. and 10:00 p.m. MDT. Load Control 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 Load Control Events. Participating
Customers will receive advance notification on or about four hours prior to the Load Control Event. The
Company will provide notice of a Load Control 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/Agreement. If prior notice of a pending Load Control Event has been sent, the
Company may choose to revoke the Load Control Event initiation and will provide notice to Participants
no less than 30 minutes prior to the Load Control Event.
INTERRUPTION OPTIONS
At the Participant’s election, and subject to Company discretion, participation in the Program may
occur via one of the following Interruption Options:
Manual Dispatch Option. Customers are eligible to manually control their Facility Site(s). Under
the Manual Dispatch Option customers have the flexibility to choose which loads will be interrupted during
each dispatched Load Control Event.
Automatic Dispatch Option. A dispatchable Load Control Device, provided and installed by the
Company or its representative, will be connected to the electrical panel(s) serving the loads associated
with the Facility Site(s) enrolled in the Program. The Load Control Device utilized under the Automatic
Dispatch Option will provide the Company the ability to send a signal intended to interrupt operation of a
particular load or service during dispatched Load Control Events. In lieu of the Company or its
representative installing the Load Control Device at the Company’s expense, the Participant may elect
to hire a licensed electrician, at the Participant’s expense, to install the Load Control Device in accordance
with the National Electrical Code (“NEC”) and any Idaho Power or manufacturer specifications or
requirements.
REQUIREMENTS OF PARTICIPATING FACILITIES
Participants will have the flexibility to choose what equipment will be used to reduce the
Nominated kW during each Load Control Event. Participants must notify the Company of their Nominated
kW via the Program Application/Agreement. Once the Program Season begins, the Participant must
submit the nomination change request form online (located at www.idahopower.com/flexpeak) via email
by MondayThursday 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 Load Control Event is called. After the third Load Control Event is called, the Nominated kW
may still be raised or lowered, but may not exceed the highest Nominated kW prior to the third Load
Control Event being called.
Idaho Power Company Third Fourth Revised Sheet No. 82-5
Cancels
I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
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.
When a Load Control 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 Load
Control 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 Load Control Event, a Nominated kW Incentive Adjustment will apply.
For Load Control 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. At its discretion, the
Company may waive all or a portion of an Incentive Adjustment should it be determined that, at no fault
of the customer, the Load Control Device utilized for the Automatic Dispatch Option did not work during
a Load Control Event.
Fixed Capacity Payment Rate*
(*to be prorated for partial weeks) Variable Energy Payment Rate*
(*does not apply to first four Load Control Events)
$3.25 per Weekly Effective kW Reduction
$0.20 per kWh
Idaho Power Company First Revised Sheet No. 82-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
INCENTIVE STRUCTURE
Incentive payments will be determined based on a Fixed Capacity Payment, and 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.
The Fixed Capacity Payment Rate will be determined by the Average Season Performance
Percentage during the Program Season. For example, if a Participant’s Average Season Performance
Percentage is 65 percent, then their Fixed Capacity Payment Rate is $2.44 per kW.
When a Load Control Event is called and a Participant exceeds the Nominated kW, the Fixed
Capacity Payment will be capped at 20 percent above original Nominated kW.
Average Season Performance Percentage Fixed Capacity Payment Rate per kW*
(*to be prorated for partial weeks)
75% - 120% $3.25
50% - 74.99% $2.44
25% - 49.99% $1.63
Greater than 0% - 24.99% $0.81
Participants are expected to reduce their load
by the Nominated kW during each hour of each Load
Control 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 Load Control Event, a Nominated
kW Incentive Adjustment will apply.
For Load Control 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. At its discretion, the
Company may waive all or a portion of an Incentive Adjustment should it be determined that, at no fault
of the customer, the Load Control Device utilized for the Automatic Dispatch Option did not work during
a Load Control Event.
At its discretion, the Company may apply a Performance Waiver should it be determined that, at
no fault of the Participant, the Load Control Device utilized for the Automatic Dispatch Option did not work
during a Load Control Event.
TERMS AND CONDITIONS
Upon acceptance into the Program, Participants agree to the provisions of this Schedule and to
the following terms and conditions:
Variable Energy Payment Rate*
(*does not apply to first four Load Control Events)
$0.20 per kWh
Idaho Power Company First Revised Sheet No. 82-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
1. Once accepted into the Program, Participants will automatically be re-enrolled each year
thereafter unless notice of termination is given by the other party.
2. Both the Company and the Participant may terminate participation in the Program
at any time by notifying the other party in writing.
3. 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. If Program
participation is terminated, the Participant may not re-enroll the Facility Site(s) into the
Program until the following calendar year.
4. The Company retains the sole right to determine the criteria under which a Load Control
Event is called and the decision of whether to call for, initiate, or cancel a Load Control
Event shall be at the Company’s sole discretion.
5. 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, amount of capacity provided at a Facility Site, availability of
Program equipment, facility system configuration, or electric system configuration.
6. Participants that choose to participate in the Program under the Automatic Dispatch
Option grant the Company or its representative permission, on reasonable notice, to enter
the Customer’s enrolled Facility Site(s) to install, service, maintain, and/or remove Load
Control Device(s) on the electrical panel that services the anticipated load reduction. The
Company retains the sole right for its employees and its representatives to install or not
install Load Control Devices on the Customer’s electrical panel at the time of installation
depending on, but not limited to, safety, reliability, or other issues that may not be in the
best interest of the Company, its employees, or its representatives.
7. If there is evidence of the Participant altering, tampering, or otherwise interfering with the
Company’s ability to initiate a Load Control Event, the Customer’s participation in the
Program will be terminated, and the Customer will be required to reimburse the Company
for all costs for replacement or repair of the Load Control Device(s) or other Program
equipment, including labor and other related costs, and the Company will reverse any and
all incentive payments made during the previous twelve months as a result of the
Customer’s participation in the Program.
Idaho Power Company First Revised Sheet No. 82-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 82-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 3, 2023 1221 West Idaho Street, Boise, Idaho
SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)
TERMS AND CONDITIONS (Continued)
5. 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, amount of capacity provided at a Facility Site, availability of
Program equipment, facility system configuration, or electric system configuration.
6. Participants that choose to participate in the Program under the Automatic Dispatch
Option grant the Company or its representative permission, on reasonable notice, to enter
the Customer’s enrolled Facility Site(s) to install, service, maintain, and/or remove Load
Control Device(s) on the electrical panel that services the anticipated load reduction. The
Company retains the sole right for its employees and its representatives to install or not
install Load Control Devices on the Customer’s electrical panel at the time of installation
depending on, but not limited to, safety, reliability, or other issues that may not be in the
best interest of the Company, its employees, or its representatives.
7. If there is evidence of the Participant altering, tampering, or otherwise interfering with the
Company’s ability to initiate a Load Control Event, the Customer’s participation in the
Program will be terminated, and the Customer will be required to reimburse the Company
for all costs for replacement or repair of the Load Control Device(s) or other Program
equipment, including labor and other related costs, and the Company will reverse any and
all incentive payments made during the previous twelve months as a result of the
Customer’s participation in the Program.
SPECIAL CONDITIONS
The Company is not responsible for any direct, indirect, consequential, incidental, punitive, or
exemplary damage to the Participant or third parties as a result of the Program or the Customer’s
voluntary participation in the Program.
The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Load Control Device(s) and any and all implied warranties are disclaimed.
Advance Notification Option. The Company reserves the right to use flexibility on the timing of
event notification for eligible customers nominating 3 MW or more.
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.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-23-24
IDAHO POWER COMPANY
ATTACHMENT 3
SEE ATTACHED EXCEL SPREADSHEET