20150204Application.pdf

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An IDACORP CompanY
LISA D. NORDSTROM
Lead Counsel
I [e-mail]
lffI5 Ft|] -tr PH
February 4,2015
VIA HAND DELIVERY
Jean D. Jewell, Secretary
ldaho Public Utilities Commission
PO Box 83720
Boise, lD 83720-0074
RE: Case No. IPC-E-15-03
Application for Approval of New Tariff Schedule 82, A Commercial and lndustrial
Demand Response Program (Flex Peak Program)
Dear Ms. Jewell:
Enclosed for filing in the above matters please find duplicate originals and seven (7) copies
of ldaho Power Company's Application.
Also enclosed for filing are duplicate originals and eight (8) copies each of the Direct
Testimony of Tami White and Quentin Nesbitt. One copy of each of the aforementioned testimonies
has been designated as the "Reporter's Copy." ln addition, two disks containing Word versions of
each of the testimonies are enclosed for the Reporter.
Very truly yours,
LDN/KKI
Enclosures
LISA D. NORDSTROM (lSB No. 5733)
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
I nord strom @ idahopower. com
Attorney for ldaho Power Company
IN THE MATTER OF IDAHO POWER
COMPANY'S APPLICATION FOR
APPROVAL OF NEW TARIFF SCHEDULE
82, A COMMERCIAL AND INDUSTRIAL
DEMAND RESPONSE PROGRAM (FLEX
PEAK PROGRAM).
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-15-03
APPLICATION
Idaho Power Company ("!daho Powe/' or "Company"), in accordance with ldaho
Code S 61-503 and RP 52, hereby respecffully applies to the ldaho Public Utilities
Commission ("Commission") for an order authorizing ldaho Power to implement an
optional program, Schedule 82, Flex Peak Program, and to continue recovering demand
response expenses in the manner it currently does ("Application"). The Flex Peak
Program ("Program") is a voluntary, internally-managed demand response program for
commercial and industrial ("C&l') customers who are willing and able to reduce their
electrical energy loads for short periods during summer peak days. ldaho Power
requests that the Commission issue an order approving this Application by May 1,2015,
Pii tr: l+3
APPLICATION - 1
to allow the Company 45 days to solicit participants prior to the June 15,2015, start of
the Program season.
ln support of this Application, ldaho Power represents as follows:
I. BACKGROUND
ldaho Power has offered the Program (previously known as the FlexPeak
Management program) to C&l customers since 2009 and had contracted with a third
party to manage it. Since its inception, the FlexPeak Management program acquired
between 8.5 megawatts ("MW") and 39.3 MW of nominated generation-level reductions
per Program season. ldaho Power Senior Manager of Rate Design Tami White
describes the evolution of the FlexPeak Management program in greater detail in
prefiled direct testimony that accompanies this Application.
2. Demand Response Proqrams Settlement Aqreement. !n Order No. 32923
issued in Case No. IPC-E-13-14, the Commission approved a Demand Response
Programs Settlement Agreement ("Settlement Agreement") regarding the design of
ldaho Powe/s three demand response programs. Section I of the Settlement
Agreement, which can be found as Exhibit No. 1 to Ms. White's testimony, established
parameters surrounding the Company's C&l demand response program participation,
program details, and the incentive structure.
3. Idaho Power incorporated these parameters into the proposal presented in
this Application to intemally manage the Program going forward. Under Section 9.a. of
the Settlement Agreement, the Company would not actively seek to expand the capacity
of the Program beyond 35 MW. Section 9.b. required that the Program will be available
from June 15 through August 15, Mondaythrough Friday, from 2:00 p.m. - 8:00 p.m.,
excluding holidays. Each dispatch event will last up to four hours per participant within
APPLICATION - 2
the available Program hours and cumulatively will not exceed 60 hours per season. In
the event of a system emergency, demand response capacity from the Program may be
ca!!ed. ldaho Power will conduct a minimum of three dispatch events per season with
two hours advance notice to participants.
4. Settlement Agreement Section 9.c. makes clear that a fixed and variable
incentive structure may be appropriate, as long as the variable portion is low enough
that it does not prevent the Program from being dispatched. lf a fixed and variable
incentive structure is used, a minimum of three dispatch events will be included in the
fixed incentive. The variable incentive will be paid to participants if Idaho Power
conducts dispatch events in the C&l demand response program for more than the three
minimum dispatch events. Parties to the Settlement Agreement also agreed on the
annual value of ldaho Power's demand response portfolio as set forth in Section 6.
5. lntesrated Resource Planninq. The preferred portfolio of the 2013
lntegrated Resource Plan accepted for filing by the Commission in Order No. 32980
assumes a demand response capacity of 50 MW is available beginning in 2024 and
steps up to approximately 370 MW by 2032. ldaho Power considers demand response
a committed resource and 390 MW (including the C&! program) of demand response
will be included in each portfolio that is analyzed as part of the 2015 lntegrated
Resource Planning process.
6. Request For Prooosal ("RFP"). ln the Settlement Agreement, ldaho
Power committed to offer its demand response programs for 2014 and beyond until a
change occurs in the Company's system operations or cost-effectiveness of a demand
response program that would warrant reevaluation of the Settlement Agreement's term.
Settlement Agreement, Section 3. !n anticipation of the expiration of the third-party
demand-aggregator agreement in December 2014, the Company issued a RFP during
APPLICATION - 3
the summer of 2014 seeking third-party assistance operating a C&l demand response
program beyond 2014. ldaho Power did not ultimately identify a successful bidder
because the Company concluded it could achieve cost savings for customers by
managing the program itself rather than through a third party.
7. Stakeholder Input. The Company solicited stakeholder preferences and
support from its Energy Efficiency Advisory Group ("EEAG') on Friday, January 9, 2015,
for either renewing the contract with the third-party administrator or having the Company
administer the program. As described more fully in Ms. White's testimony, the majority
of EEAG members appeared to be cautiously supportive of an ldaho Power-managed
program; however, one EEAG member expressed a neutral position and another EEAG
member recommended the Company retain EnerNOC, lnc. as the third-party manager
of the Program.
II. COMPANY.ADMINISTERED FLEX PEAK PROGRAM PROPOSAL
8. Prooram Desiqn. The Company's proposal to internally manage the
Program is described in the testimony of Quentin Nesbitt, ldaho Power Energy
Efficiency Program Leader, that accompanies this Application and in Schedule 82, Flex
Peak Program, which can be found as Attachment 1 to this Application. The proposed
optional Program will be available to C&l customers taking service under Schedules 9,
19, or a Special Contract. The Program will be promoted to past C&l demand response
program participants and, as explained more fully in Schedule 82, those customers who
intend to participate will be required to file an application with the Company prior to the
start of each Program season. The program season will run from June 15 - August 15.
Program events will be called only between the hours of 2:00 p.m. - 8:00 p.m., Monday
through Friday, excluding holidays. Program events may last two to four hours per day
and will not exceed 15 hours per calendarweek and 60 hours per Program season.
APPLICATION - 4
Participants wil! be notified two hours prior to a Program event. A minimum of three
Program events per season will be called.
L lncentive Pavments. The proposed Program incentive structure includes
both fixed and variable payments. The proposed fixed payment will be equal to $3.25
per kilowatt ('kW") per week multiplied by the amount of actual kW reduction received
during a Program event or, in the absence of a Program event, the actual kW reduction
will be equal to the nominated kW. The proposed variable payment will be equal to
$0.16 per kilowatt-hour reduced, effective after the first three Program events have
been called for the Program season. The kW reduction will be calculated from a
baseline using the three highest average participant non-event load days in the prior 10
days before an event day. Payments to participants will be in the form of a check
distributed within 30 days of the end of each Program season.
10. Customer Benefits. There are several benefits to participants of a
Company-managed program. First and as more fully described in Ms. White's
testimony, the Company has identified cost savings per kW of load reduction if it
internally manages the Program. The cost savings would be passed on directly to the
entire body of customers, both participants and non-participants. Second, the Company
has repeatedly heard from customer groups that they would value increased
transparency regarding the terms of the agreement between a third-party provider and
the participating customers. lf the Company offered a program, each participating
customer would be required to adhere to the terms and conditions identified in the
publically available tariff schedule and receive consistent incentive payments for doing
so.
11. Proqram Timino. lf ldaho Power receives a Commission-approved tariff
schedule by May 1, 2015, such that it has 45 days to solicit participants, the Company
APPLICATION - 5
believes that it can implement the Program by June 15, 2015, as envisioned in the
Settlement Agreement.
!II. PROGRAM COST.EFFECTIVENESS
12. Demand Response Portfolio. According to the above-described
Settlement Agreement, the annual value of ldaho Power's demand response portfolio is
equal to the levelized annual cost of the minimum size deferred resource, which was
calculated in the Settlement Agreement to be approximately $16.7 million. !n 2014, the
cost of operating the Company's entire demand response portfolio was $10.6 million,
well under the $16.7 million threshold. lf al! three demand response programs were
dispatched for the maximum allowable number of hours, the costs would have been
approximately $1 3.8 million.
13. Proqram Cost Savinos. The Company estimates that it can operate the
Program for less cost than it could by contracting with a third-party operator, in which
case the total demand response expense wil! be reduced accordingly. Based on the
Company's proposed Program design, the Company anticipates total Program costs to
range from approximately $1.1 million annually with no variable payments up to
approximately $1.4 million if the Program has 35 MW of nominated reductions and was
dispatched for the maximum number of hours allowed, which is 60.
14. No Rate Chanqe. ldaho Power does not propose a change to customer
rates associated with the ongoing funding of the Program. The Company believes that
the current level and method of recovery will adequately fund the ongoing operation of
the Program for the foreseeable future.
IV. FLEX PEAK PROGAM COST RECOVERY
15. Demand Response Incentives in Rate Base. On December 30,2011, the
Commission issued Order No. 32426 in Case No. IPC-E-11-08 approving approximately
APPLICATION - 6
$11.3 million of normal or "base level" demand response incentive payment costs to
become part of base rates effective January 1, 2012. Of that base level amount,
approximately $2 million was associated with C&l demand response program costs.
The demand response cost recovery method approved by Order No. 32426 authorized
the Company to move demand response incentive payment costs into base rates and
track deviations as part of the annual Power Cost Adjustment ('PCA') mechanism.
16. Demand Response lncentives in the PCA. Annually, as part of the PCA,
the forecasted level of demand response incentive payments would be compared to the
normal level included in base rates to determine the level of demand response incentive
payment cost recovery or credit to be included in the PCA forecast. One hundred
percent of any deviations between actual demand response incentive payment costs
and forecasted costs would be included in the following year's PCA true-up. lt should
also be noted that the demand response costs recovered in base rates and tracked
through the PCA would include only the incentives paid to participants for demand
reduction or the total amounts paid to third-party demand-aggregator contractors for
demand reduction; ldaho Power labor associated with administration of the demand
response programs would continue to be recovered through the Energy Efficiency
Rider.
17. Flex Peak Cost Recoverv. The current level of C&l demand response
program costs recovered through base rates is the same level approved by Order No.
32426, approximately $2.0 million a year. lf approved, the Company anticipates
Program incentive payment costs to range from approximately $0.9 million annually with
no variable payments up to approximately $1.27 million if the Program was dispatched
for the maximum number of hours allowed.
APPLICATION - 7
18. ldaho Power requests that this regulatory treatment of Program demand
response expenses continue unchanged with the implementation of Schedule 82.
Under the current regulatory treatment of demand response cost recovery, ldaho Power
would recover Program incentive payment costs through base rates, with deviations
from the base level tracked through the PCA mechanism. Continuing the use of the
PCA mechanism to track deviations between actual Program incentive payment costs
and those recovered in base rates will allow 100 percent of any annual Program cost
savings to flow to customers by June of the following year. The Company would
continue to recover Program labor and other administrative expenses through the
Energy Efficiency Rider.
19. ldaho Power will report in its DSM Annual Report on all activities
associated with the Program including how it impacts the Energy Efficiency Rider, as
well as detailing the incentives to be included in the PCA calculation.
V. MODIFIED PROCEDURE
20. ldaho Power believes that a hearing is not necessary to consider the
issues presented herein and respectfully requests that this Application be processed
under Modified Procedure, i.e., by written submissions rather than by hearing. RP 201
ef seg. lf, however, the Commission determines that a technica! hearing is required, the
Company stands ready to present the direct testimonies of Tami White, Senior Manger
of Rate Design, and Quentin Nesbitt, Energy Efficiency Program Leader, that
accompany this Application and support the Application in such hearing.
V. COMMUNICATIONS AND SERVICE OF PLEADINGS
21. Communications and service of pleadings with reference to this
Application should be sent to the following:
APPLICATION - 8
Lisa D. Nordstrom
ldaho Power Company
122'l West Idaho Street (82702)
P.O. Box 70
Boise, ldaho 83707
I no rd strom @ id a hopower. co m
dockets@idahopower. com
TamiWhite
Quentin Nesbitt
ldaho Power Company
1221West ldaho Street (82702)
P.O. Box 70
Boise, ldaho 83707
[e-mail]
q nesbitt@idahopower. com
VI. REQUEST FOR RELIEF
22. ldaho Power respectfully requests that the Commission issue an Order
authorizing: (1) this matter to be processed by Modified Procedure, (2) ldaho Power to
implement optional Schedule 82, Flex Peak Program, and (3) ldaho Power to continue
recovering Flex Peak Program expenses in the same manner it cunently recovers its
C&l demand response program expenses.
DATED at Boise, ldaho, this 4th day of February 2015.
D. NOR TROM
APPL]CATION - 9
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO, IPC.E-15.03
IDAHO POWER GOMPANY
ATTACHMENT 1
ldaho Power Company
!.P.U.C. No. 29, Tariff No. 101 OriqinalSheet No. 82-1
SCHEDULE 82
FLEX PEAK
PROGRAM
(oPTroNAL)
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.
AVA!LABILITY
The Program is available to Commercial and lndustrial 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. lf 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 during 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.
Adiusted Baseline kW. The Original Baseline kW plus or minus the "Day of' Load Adjustment
amount.
Aqoreoated 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 metering data from each enrolled Facility Site before calculating
any incentive amounts.
IDAHO
lssued per Order No.
Effective - May 1',2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company
I.P.U.C. No. 29. Tariff No. 101 Oriqinal Sheet No. 82-2
SCHEDULE 82
FLEX PEAK
PROGRAM
(oPTroNAL)
DEFIN ITIONS (Continued)
Business Davs. Any day Monday through Friday, excluding holidays. For the purposes of this
Program, lndependence Day is the only holiday during the Program Season. lf lndependence Day falls
on Saturday, the preceding Friday will be designated the holiday. lf !ndependence Day falls on Sunday,
the following Monday will be designated the holiday.
Capacitv Pavment. The Weekly Effective kW Reduction multiplied by the Capacity Payment
rate (as described in the Incentive Structure section).
"Dav of' Load Adiustment. 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 an
event. 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.
Enerov Pavment. 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 lncentive Structure section). The Energy Payment does not apply to the first three Program
Events.
Event Availability Time. Between 2:00 p.m. and 8:00 p.m. Mountain Daylight Time (MDT) each
Business Day.
Facilitv 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.
Hiqhest Enerov Usaoe Davs. The three days out of the immediate past 10 non-event Business
Days that have the highest average 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.
IDAHO
lssued per Order No.
Effective -'M?y 1', 2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company
I.P.U.C. No. 29. Tariff No. 101 OrioinalSheet No. 82-3
SCHEDULE 82
FLEX PEAK
PROGRAM
(oPTroNAL)
DEFIN ITIONS (Continued)
Nominated kW lncentive Adiustment. 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 tota! Nominated kW lncentive Adjustment will not
exceed the total incentive amount for the Program Season (as described in the lncentive Structure
section).
Notification of Proqram 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.
Orioina! Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days
during the Event Availability Time, calculated for each Facility Site.
The following table provides an example of the calculation of the Original Baseline kW between hours
of 2:00 p.m. and 8:00 p.m. using the (3) Highest Energy Usage Days of 5, 7, and 9.
Day 2-3 PM
(kw)
3.4 PM
(kw)
4.5 PM
(kw)
5.6 PM
(kw)
6.7 PM
(kwl
Average
7-8 PM Usage(kw) (kwl
L
2
3
4
3000
3200
3100
32s0
3100
3100
3200
3400
3000
3200
3100
3300
3200
3200
3100
3400
3000
3100
3200
3300
3200
3300
3100
3400
3083
3183
3133
3342
6 3100 3000 3200 3100 3100 3200 3tL7
8 3300 3200 3300 3300 3300 3200 3267
10 32s0 3300 3300 3200 3200 3200 3242
Original
Baseline(kwl 3367 3400 3350 3357 3433 3400
Participant. Any Customer who has a Facility Site that has been accepted into the Program.
Prooram Apolication. Written form submitted by a Customer who requests to enroll a Facility
Site in the Program.
IDAHO
lssued per Order No.
Effective - May 1,2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho'
ldaho Power Company
I.P.U.C. No. 29. Tariff No. 101 Orioinal Sheet No. 82-4
SCHEDULE 82
FLEX PEAK
PROGRAM
(oPTroNAL)
DEFI NITIONS (Continued)
Prooram Event. A time period when the Company requests or calls for reduction of the
Nominated kW.
Prooram Season. June 1Sth through August 15h of each year.
Proqram Week. Monday through Friday.
Variable Prooram 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 three Program Events.
Weeklv 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 2:00 p.m. and 8:00 p.m. MDT. Program Events will last between two to four
hours per day and will not exceed 15 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 at least two hours prior to the Program Event.
The Company will provide notice of a Program Event via the following communication technologies:
telephone and e-mail to the designated contact(s) submitted by the Participant in the Program
Application. lf 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.
REQU IREMENTS OF PARTICIPATI NG FAC!LITIES
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 contact the
Company via phone or 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 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
lncentive payments will be determined based on a Capacity Payment, an Energy Payment, and
any applicable Nominated kW lncentive Adjustment. Both the Capacity and Energy Payments will be
paid by check no more than 30 days after the Program Season concludes on August 15th.
!DAHO
lssued per Order No.
Effective - May 1,2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company
LP.U.C. No. 29. Tariff No. 101 Orioinal Sheet No. 82-5
SCHEDULE 82
FLEX PEAK
PROGRAM
(oPTroNAL)
INCENTIVE STRUCTURE (Continued)
When a Program Event is called and a Participant exceeds the Nominated kW the Capacity
Payment will be capped at 20 percent above original Nominated kW.
Capacitv Pavment Rate*
(*to be prorated for partial weeks)
Enerqv Pavment Rate*
('does not apolv to first three Proqram Events)
$3.25 per Weekly Effective kW Reduction $0.16 per kWh
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 lncentive Adjustment will apply.
For the first three Program Events, the Nominated kW lncentive 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 lncentive Adjustment will be $0.25 per kW for each hour the Nominated kW
is not achieved during that interval.
The total Nominated kW lncentive Adjustments will not exceed the total incentive amount for the
Program Season.
TERMS OF PARTICIPATION
Participants must submit a Program Application annually prior to the start of the Program
Season. This Program Application must include the Facility Site(s) they wish to enroll and the initial
Nominated kW for each Facility Site. !f 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 or any other time that a Participant'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
lssued per Order No.
Effective - May 1,2015
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho