20220110IPC to Staff 29.pdf

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LISA D. NORDSTROM
Lead Counsel
[e-mail]
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Attachments
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January 10,2022
VIA ELECTRONIC FILING
Jan Noriyuki, Secretary
ldaho Public Utilities Commission
11331 West Chinden Blvd., Building 8
Suite 201-A
Boise, ldaho 83714
Re: Case No. IPC-E-21-32
ln the Mafter of ldaho Power Company'sApplication forApprovalto Modiff
Its Demand Response Programs
Dear Ms. Noriyuki:
Aftached for electronic filing, pursuant to Order No. 35058, is ldaho Power
Company's Response to Request for Production No. 29 to the Second Production
Request of the Commission Staff to ldaho Power Company in the above entitled matter.
The remaining responses will be submitted on January 28,2022.
lf you have any questions about the attached documents, please do not hesitate
to contact me.
Very truly yours,
&; !.7("t-t^.^,
Lisa D. Nordstrom
LISA D. NORDSTROM (lSB No. 5733)
ldaho Power Company
1221 West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
Attorney for ldaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO PO\A/ER
COMPANY'S APPLICATION FOR
APPROVAL TO MODIFY ITS DEMAND
RESPONSE PROGRAMS.
CASE NO. IPC-E-21-32
IDAHO POWER COMPANY'S
RESPONSE TO REQUEST NO. 29
TO THE SECOND PRODUCTION
REQUEST OF THE COMMISSION
STAFF TO IDAHO POWER
COMPANY
COMES NOW, ldaho Power Company ("ldaho Powef or'Company'), and in
response to Request for Production No. 29 to the Second Production Request of the
Commission Staff ("Staff') dated January 7,2022, herewith submits the following
information:
IDAHO POWER COMPANY'S RESPONSE TO REQUEST NO. 29 TO THE SECOND PRODUCTION
REQUEST OF THE COMMISSION STAFF TO IDAHO POI/VER COMPANY.l
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REQUEST FOR PRODUCTION NO. 29: Please provide copies of all past and future
data requests and responses received by or sent from ldaho Power to the Public Utility
Commission of Oregon for the Tariff Advice No. 21-12 Proposed Modifications to the
Company's Demand Response Programs. Please include both formal and informal
responses. This response should include public and confidentialdata responses.
Please provide allfuture responses at, or shortly after, the time when the Company files
its responses to the request.
RESPONSE TO REQUEST FOR PRODUCTION NO. 29:
Please see Attachment No. 1 to this request for the informal request and
response between the Oregon Public Utility Commission ("OPUC") Staff and ldaho
Power related to ADV13SS/Advice No.21-12. Please see Attachment No. 2 to this
request for the formal Data Request Nos. 1-29 issued by the OPUC Staff on December
15,2021 in ADV1355/Advice No.21-12 and Attachment No. 3 for ldaho Power
Company's responses to Data Requests Nos. 1-29, which were submitted to the OPUC
on December 29, 2021.
The response to this Request is sponsored by Connie Aschenbrenner, Rate
Design Senior Manager, ldaho Power Company.
IDAHO POWER COMPANY'S RESPONSE TO REQUEST NO. 29 TO THE SECOND PRODUCTION
REQUEST OF THE COMMISSION STAFF TO IDAHO POWER COMPANY.2
DATED at Boise, ldaho, this 1CIh day of January 2022.
&L.O-ff^*t**-
LISA D. NORDSTROM
Attomey for ldaho Porer Company
IDAHO POVI'ER COMPANY'S RESPONSE TO REQUEST NO. 29 TO THE SECOND PRODUCNON
REQUEST OF THE COMMISSION STAFF TO IDAHO POV\ER COMPA}IY- 3
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 10th day of January 2022, ! served a true and
correct copy of ldaho Power Company's Response to Request No. 29 to the Second
Production Request of the Commission Staffto ldaho Power Company upon the following
named parties by the method indicated below, and addressed to the following:
Commission Staff
Riley Newton
Deputy Attomey General
ldaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg No. 8,
Suite 201-A(837141
PO Box 83720
Boise, lD 83720-0074
ldaho lrrigation Pumpers Association, lnc.
Eric L. Olsen
Echo Hawk & Olsen, PLLC
505 Pershing Ave., Ste. 100
P.O. Box 6119
Pocatello, ldaho 83205
Lance Kaufrnan
Aegis lnsight
4801 W. Yale Ave.
Denver, CO 80219
ldaho Conservation League
Benjamin J. Otto
Emma E. Sperry
ldaho Conservation League
710 N. 6th Street
Boise, ldaho 83702
lndustrial Customers of ldaho Power
Peter J. Richardson
Richardson Adams, PLLC
515 N. 27th Street
P.O. Box 7218
Boise, ldaho 83702
_Hand Delivered_U.S. Mai!
_Overnight Mail_FAX
FTP SiteX Emai!: [e-mail]
_Hand Delivered
_U.S. Mai!
Overnight Mail_FAX_ FTP SiteX Email [e-mail]
_Hand Delivered
_U.S. Mail
Overnight Mail
_FAX
FTP Site
x EMAIL [e-mail]
_Hand Delivered
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_FAX_ FTP SiteX EMAIL [e-mail]
espe rrv@ id a hoco nse rvatio n. orq
_Hand Delivered
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Overnight Mail
_FAX_ FTP SiteX EMAIL [e-mail]
IDAHO POVVER COMPANY'S RESPONSE TO REQUEST NO.29 TO THE SECOND SET OF
PRODUCTION REQUEST OF THE COMMISSION STAFF TO IDAHO PO\'\IER - 4
Dr. Don Reading
6070 Hil! Road
Boise, Idaho 83703
Micron Technology, lnc.
Austin Rueschhoff
Thorvald A. Nelson
Austin W. Jensen
Holland & Hart LLP
555 17th Street, Suite 3200
Denver, CO 80202
Jim Swier
Micron Technology, lnc.
8000 South FederalWay
Boise, lD 83707
Boise City
Ed Jewell
Deputy City Attorney
Boise City Attorney's Office
150 N. Capitol BIvd. P.O. Box 500
Boise, !D 83701-0500
_Hand Delivered
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_Overnight Mail
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Overnight Mail
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FTP SiteX EMAIL [e-mail]
tne lson @ holla nd ha rt.com
awien sen@h olland ha rt. com
aclee@ h olla nd ha rt. com
qlqarqanoamari@hollandha rt.com
_Hand Delivered
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Overnight Mail
_FAX_ FTP SiteX EMAIL [e-mail]
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FTP SiteX EMAI L eiewell(Oc ityofboise.orq
[e-mail]
')tcrcr.ro tl-.r.r-,
Stacy Gust, Regulatory Administrative
Assistant
IDAHO PO\A/ER COMPANY'S RESPONSE TO REQUEST NO. 29 TO THE SECOND SET OF
PRODUCTION REQUEST OF THE COMMISSION STAFF TO IDAHO PO\A'ER.5
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPG-E-21-32
IDAHO POWER GOMPANY
REQUEST NO. 29
ATTACHMENT NO. 1
From: BROCKMAN Kacia * PUC <[e-mail]>
Sent: Friday, December 3,202111:59 AM
To: Thompson, Zack <ZThom pson@ ida hopowe r. com >
Cc: SAYEN Nick * PUC <[e-mail]>
Subiect: [EXIERNAL]RE: Advice No. 21-12 questions
KEEP IDAHO POWER SECURE! External emails may request information or contain malicious links or attachments. Verify
the sender before proceeding, and check for additional warning messages below.
Hi Zack,
Thanks for the information, and we appreciate the prompt reply
Hope you have a great weekend.
Kacia Brockman
Oregon Public Utility Commission
s03-931-9658
From: Thompson, Zack <ZThom pson @ ida hopower.com>
Sent: Friday, December 3,2O2L 9:23 AM
To: BROCKMAN Kacia * PUC <[e-mail]>
Cc: SAYEN Nick * PUC <[e-mail]>
Subject: RE: Advice No. 21-12 questions
HiKacia,
Below are the response to your two questions. Please let me know if you need anything else, and have a nice weekend
1. We reached out to IPUC Staff to confirm, and you can contact Terri Carlock ([e-mail]) and/or
Donn English (Donn. [e-mail]).
2. The Company's primary objective is to ensure it has a consistent program to offer across its service area and it
has adequate time to market the program to solicit participation and install devices for the lrrigation and
residential AC program. lf the ultimate program parameters are consistent between the two jurisdictions, ldaho
Power can manage around a later Oregon effective date than in ldaho due to the relatively small market of DR
potential in our Oregon service area. lt will cause some issues with creating separate sign-up mailings especially
with irrigation customers that operate in both states. An order received no later than early March would be ideal.
lf the jurisdictions ultimately order differing programs, the Company may not be in a position to implement in
advance otlhe2022 DR season.
Regards,
Zack Thompson
REGULATORY ANALYST
ldaho Power I RegulatoryAffairs
Office 208-388-2982 | Mobile [phone]
1
From: BROCKMAN Kacia * PUC <[e-mail]>
Sent: Thursday, December 2,20213:28 PM
To: Thompson, Zack <ZThom oson@ ida hopower.com>
Cc: SAYEN Nick i PUC <[e-mail]>
Subject: [EffERNALlAdvice No. 21-12 questions
KEEP IDAHO POWER SECURE! External emails may request information or contain malicious links or attachments. Verify
the sender before proceeding, and check for additiona! warning messages below.
Hi Zack,
l'm supporting Nick Sayen in his review of ldaho Powe/s filing to modifo the Company's demand response programs. We
have two questions for you:
1. Can you please share with us the contact info for IPUC Staff person that is leading the review of your equivalent
application in ldaho? We'd like to touch base with them on a couple of issues.
2. The requested effective date for the filing is Feb. 15, 2022.ls there possibly a later effective date that would still
allow sufficient time to implement the program changes and recruit new customers prior to the summer 2022
season? We are planning our workload and there are numerous other priorities that need Staff attention during
the same time frame as ldaho Power/s filing.
Thankl Feel free to give me a call at the number below if that's easier
Kocia Brockmon (she/her)
Senior Utility Anolyst o Energy Resources and Planning
Oregon Public Utility Commission
201 High Street SE o Solem, OR 97301
c: [phone]
ko cio. brockmo n @ puc.oreao n.o ov
7 Oregon
0'i:rJr,:"
IDAHO POWER LEGAL DISCIAIMER
This transmission may contain information that is privileged, confidential and/or exempt from disclosure
under applicable law. lf you are not the intended recipient, you are hereby notified that any disclosure,
copying, distribution, or use of the information contained herein (including any reliance thereon) is STRICTLY
PROHIBITED. tf you received this transmission in error, please immediately contact the sender and destroy the
material in its entirety, whether in electronic or hard copy format. Thank you.
2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPG-E-21-3:2
IDAHO POWER GOMPANY
REQUEST NO 29
ATTACHMENT NO.2
Docket No.
ADV 1 355/Advice No. 21-12
OPUC Reouest Nos.
tR 1- 29
Public Utility Commission
201 High st sE suite 100
Salem, OR 97301
Mailing Address: PO Box 1088
Salem, OR 97308-1088
Consumer Services
7-800-522-2404
Local: 503-378-6600
Administrative Services
503-373-7394
Resoonse Due Bv
December 29,2021
regon
Kate Brown, Govcrnor
December 15,2021
IDAHO POWER COMPANY
P.O. BOX 70
1221W.IDAHO STREET
BOISE, lD 83702
RE:
Please provide responses to the following request for data by the due date. Please note that al!
responses must be posted to the PUC Huddle account. Contact the undersigned before the
response due date noted above if the request is unclear or if you need more time. !n the event
any of the responses to the requests below include spreadsheets, the spreadsheets should be
in electronic form with cellformulae intact.
Topic or Keyword: Demand Response tariff changes
All Questions relate to Oregon residential customers served by ldaho Power except where
expressly stated othenrise.
1. Please provide the proposed tariff changes as redlines to the existing tariffs.
2. See Page 2, Table 1. Please break out the Oregon Capacity (MW and Oregon Total Cost
by program (Schedule 23,74,761.
3. See page 3 (and Attachment 2, page 2).Why does ldaho Power Company (lPC or
Company) assume no market purchases in its ELCC modeling?
4. See page 3. Please summarize the availability of market purchases to IPC in both, the top
100 gross demand hours and the top 100 highest-risk hours.
5. See page 5. Because Schedule 74 an occur throughout the day, is it more effective than
Schedule 23 and 76 which have event availability times?
6. See page 6. For an average customer on each Schedule, what proportion of a total
monthly energy bill is generally offset by the monthly DSM program credits?
Page2
December 15,2021
7. See page 6. Why are irrigation customers charged more than their incentive payment for
missing events (the proposed change from $5 per kW to $6.25 per kW versus the
proposed incentive of $5.25)? Was the Schedule 24 demand charge of $7.78 per kW
influential as a comparison in the development of these proposed rates?
8. See page 6.Why is irrigation paid more than Flex and AC per k\AP
9. Has IPC run its ELCC model by specific DSM program? lf "yes,' then please provide the
ELCC values of irrigation, Flex, and AC separately. lf "no," then please justiff why the
payment per kW is not consistent across programs.
10. Are customer event opt out rates used in any of IPC's modeling?
11. See page 8. How widespread is the occurrence of irrigation Schedule 23 customers
receiving an incentive payment even though they did not participate?
12. See page 8. ls the new installation fee cost-based?
13. See page 8. Please provide the workpaper for the new installation fee.
14. See page L Regarding the out-of-demand season energy credit, does the Company plan
to extend the in-season period for Schedule2T? ln your response, please describe how
given that later months are becoming higher risk, the Company can continue to not impose
a demand charge in later months.
15. See page 10 (and Attachment 2, page 3). Please comment generally on the capacity value
differences between DSM and combustion turbines. Did the Company's finding that DSM
only provides 55% as much capacity value as a combustion turbine surprise the
Company? ln your response please describe if the decrement to ELCCsccr is due more to
limitation in the number of DSM events that can be called or due to limitation in the number
of hours of DSM per day. ln your description please also indicate if customer event opt
outs are relevant.
16. See page 10. Generally, would using a different load and resource balance year than 2023
increase or decrease the ELCCsccr?
17. See page 1 1 (and Attachment 2, page 3). In the Company's modeling, which hours was
the DSM deployed? Was there much deployment in the 3-5pm or 10-11pm hours?
'18. See Attachment 2, page 1. What is the planning horizon?
19. See Attachment 2, page2, which describes historica! resource availability and statistical
forced outage rates. Please describe how actual historica! performance of thermal
resources are used in the Company's ELCC model.
20. See Attachment 2, page2. Where is this net load definition from? Do others use this
definition? Statistically, are there any times where there is simultaneously zero wind, solar,
PURPA resouroes, and run-of-river hydro generation on IPC's system?
21. See Attachment 2, page 3. Please describe how the groups are added and how this
process works: 'the algorithm lastly creates a dispatch pattern by adding allthe groups into
a single load shape."
Page 3
December 15,2021
22. See Attachment 2, page 4. Please define "DR effectiveness" as used on the y-axis of
Chart 1.
23. See Attachment 2, page 4-6. Please provide the LOLP values pictured in Charts 2-5.|f
these values are normalized, please also provide the raw values.
24. See Attachment 2, page 4, comparing Chart 2 to Chart 3. The scale of the y-axis has the
same Iabel in both graphs and there is no indication of changes to the demand inputs, so
why does adding resources while holding demand constant increase loss of load
probability? For example, why does Day 5, hour 21 change from blue to red between Chart
2 and Chart 3?
25. See Aftachment 2, page 7. Does IPC consider whether there are any historical correlations
between thermal resources outages and peak net-need times in its EFORs and monthly
outage tables?
26. See Attachment 2, page 7. Please describe how the dispatch shapes are computed in
"dispatch shapes for energy-limited resources such as battery storage and DR are created
based on net load."
27. See Aftachment 3, page 1 , related to critical peak pricing. Please describe generally if IPC
is underpricing its highest risk hours and if dynamic pricing is interchangeable with DSM.
28. See Attachment 4, page 2, related to critical hours from 9-11pm. PIease confirm that lPC
thinks there is a noteworthy risk of an outage after 10pm. Please provide some context
given that BPA defines light load hours as "Times of low electricity usage. For BPA, light
load hours are 10 p.m. to 6 a.m. Monday through Saturday and all day Sunday."
29. Please provide IPC's actual 100 highest peak net demand hours for each of the last 5
years.
Please name your responsive file to include the Data Request number. Once you have posted
your response to the Data Request to the PUC Huddle account, use the "Sharing" feature of
Huddle to generate an email to authorized parties notifying them that the response has been
posted. ln the body of the generated email, list the Data Request number associated with your
response.
You must mark confidentia! responses as such and post them to Huddle in the appropriate
"Confidential" folder. Access to Confidentialfolders is Iimited to individuals who have signed
the protective order. You should not send confidentialdocuments (hard copy or electronic)
separately to the Commission or its Staff; you should post confidentia! responses only to the
Huddle account.
Should you need to request an extension to the due date for the data responses you will need
to contact the staff attorney assigned to the case for approval.
Page 4
December 15,2021
Questions regarding the use of Huddle should be directed to [e-mail].
/sl Sarah Hall
Program Manager
Staff lnitiator: Nick Sayen [e-mail] 503-510*4355
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-32
IDAHO POWER COMPANY
REQUEST NO 29
ATTACHMENT NO.3
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response Tariff Ghanges
STAFF'S INFORMATION REQUEST NO. 1:
Please provide the proposed tariff changes as redlines to the existing tariffs.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 1:
Fi66-se see the attachments provided for this response.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to Staffs
First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
regon Capacity (MW and Oregon Total
Cost by program (Schedule 23,74,761
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.2:
*Costs tor 2016 and 2017 do not sum to the total in Table 1 on Page 2 due to rounding.
Year
OR A/C Cool
Credlt
Capacity
(MW)
OR Flex Peak
Capacity
(iruv)
OR lnigation Peak
Rewards Capacity
(ilrvv)
ORA'CC
Cool Crcdlt
Gogt*
OR Flex Peak
Cogt'
OR lrrlgation
Peak
Rewalds
Cost'
2020 0.37 11.40 8.30 $25.300 s207.u1 $185.395
2019 0.40 12.20 8.80 s30.762 $256.606 $179.849
2018 0.47 5.60 9.50 $36.425 s64.316 $181.502
2017 0.51 12.00 7.00 $39.493 $231.296 $206.849
2016 0.52 12.30 7.30 s41.845 $247.909 s221.351
ADV 1355/Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
pagecompany) assume no market p
does ldaho Power Company (lPC or
ELCC modeling?ln
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORTUATION REQUEST
NO. 3:
To ob-tain a resource's Effective Load Carrying Capability ('ELCC"), the perfect
generation of the system with the resouroe is subtracted from the perfect generation of
the system without the resource, and then divided by the evaluated resource's
nameplate capacity. Because a resource's ELCC is dependent on a difference
calculation (one of which both variables would include market purchases, and thus
cancel out), the addition of market purchases to the ELCC modeling would not have a
significant impact on the calculation and corresponding results.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
summa ava of market purchases to IPC in both, the
hest-risk hours.top demand hours and the top 100 hig
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.4:
TEEeompany includes 380 MW of market purchases as available in its toad and
resource balance for all hours in 2023, including the top 100 gross demand hours and
the top 100 highest-risk hours. The Company has secured severalfirm third-pafi
transmission reservations that total to 380 MW.
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 5:
r throughout the day, is it more effective
than Schedule 23 and 76 which have event availability times?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 5:
No. \A/hile Schedule 74 does not limit event availability times, the Company's analysis
determined that the highest risk hours occur between 3:00pm and 11:00pm, which
means a program that operates between the hours of 3:00pm and 11:00pm is most
effective.
ADV 1 355/ Advice No. 21 -12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 6:
See page 6. For an average customer on each Schedule, what proportion of a total
monthly energy bill is generally offset by the monthly DSM program credits?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 5:
FiEIEe see the table below.
Percentage of Energy Bill Offset by DR Program Credits for the Average
Customer
Prooram June Juh Auqust
A/C CoolCredit 5.9%3.3o/o 3.4o/o
Flex Peak 2o/o 3o/o 1o/o
lrrioation Peak Rewards '12%21o/o 12%
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO.7:
arged more than their incentive payment
for missing events (the proposed change from $5 per kW to $6.2S per kW versus the
proposed incentive of $5.25)? Was the Schedule 24 demand charge of $7.78 per kW
influential as a comparison in the development of these proposed rates?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 7:
Tfriloverall incentive structure is designed to give ldaho Power a resource that is
predictable and cost effective. The purpose of the opt-out penalty is to motivate
customers to participate during called events rather than frequently opting out and still
getting a sizeable incentive payment. Because the program is dispatched to meet
capacity deficits during a relatively small number of summer hours caused by abnormal
conditions, it is likely that Idaho Power may only run the three minimum events in a
given season.
The proposed $6.25 opt-out fee is designed to remove approximately % of the total
season incentive each time a customer opts out. The increase in the opt-out fee is
necessary with the overall increase of the incentive payment customers will receive due
to the proposed increase in the incentive amounts (both demand and energy) as wellas
the additionalmonth incentives can be earned during the program season. The current
demand charge was taken into account when setting the credit amount as it is important
that the demand credit be less than the demand charge. lf the demand credit was
greater than the demand charge, customers could potentially earn an incentive for
running their pumps for a short period of time when they otherwise would not need to.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 8:
See page 6. \My is irrigation paid more than Flex and AC per k\AP
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.8:
lrrigation Peak Rewards participants are not paid more per kilowatt fkV1fl) per season
than C&l Flex Peak customers. The $3.25 per kW is paid per week for C&l customers
and results in a potential payment for the current program of $29.25 per kW per season,
and the proposed incentive would result in in a potential payment o1$42.25 per kW per
season.
The Irrigation Peak Rewards program incentive is paid monthly resulting in
approximately $16.00 per kW per season and can vary based on the customer's overall
kilowatt-hour ("kWtr") usage. The proposed irrigation incentives and the longer season
results in a potential payment of approximately $25.00 per kW per season.
The ResidentialA/C Cool Credit program is also paid monthly. lt has the lowest
incentive payment, which is currently $15.00 per season, with the proposed being
$20.00 per season. ldaho Power sees about a 1 kW reduction per residential program
participant. Therefore, the proposed incentive is approximately $20.00 per kW per
season.
The incentive levels for the Irrigation Peak Rewards and A/C Cool Credit programs were
set as part of the Settlement Agreement approved by the Commission in Order No. 13-
482 in Docket UM 1653. The incentive levels for the Flex Peak program were set in
Advice No. 15-03, approved by the Commission at the Public Meeting on April 28,2015.
The Flex Peak program had previously been managed by a third party, and the
Company requested to internally manage the program to reduce costs and increase
transparency.
Along with the incentive levels set in the filings mentioned above, the difference in
incentives for each program is related to the relative difference in administrative costs
for each program on a per kW basis. The C&l Flex Peak program has the lowest overall
administrative costs per kW of load reduction and the Residential A/C program has the
highest overalladministrative costs per kW, with lrrigation Peak Rewards being in the
middle. Therefore, the price per kW per season is set for each program so they remain
cost-effective and incentivize participation.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO.9:
program? lf
ELCC values of inigation, Flex, and AC separately. lf "no,"
payment per kW is not consistent across programs.
"yes,
then
" then please provide the
please justify why the
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 9:
N6]'itiaho Power modeled Effective Load Carrying Capability for the Demand Response
programs as a single flexible resource as outlined in Attachment 2 to Advice No.21-12.
ln addition to the different program administration costs stated in the response to Staffs
lnformation Request No. 8, each customer class participates in the demand response
programs in a different way based on which loads are shed and the potential impacts
load reductions may have on individual customers. Therefore, each class requires
different program characteristics and incentive amounts to encourage meaningful and
reliable participation the Company can utilize to meet system needs.
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of Information Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 10:
of tPC's modeling?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 10:
While event opt-out rates were not explicitly used in ldaho Power's modeling, past
program performance (which would have included some level of customer opt-outs) was
used to validate the megawatt group sizing utilized by hour and by month.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 11:
e of irrigation Schedute 23 customers
receiving an incentive payment even though they did not participate?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. I t:
Participation to ldaho Power means the customer was willing to allow their pump to be
shut off on any given demand response event ldaho Power calls. However, the program
is designed around the concept that not all pumps will be running when events are
called and can vary based on the weather and time of the season.
Opt-outs are not widespread, so it is rare that a customer opts out of enough events to
fully negate their season incentive. The Company uses the term "opt-out" to refer to
occasions when a customer contacts the Company directly or when they manually opt
out at the device. !f the customer has not informed the Company of their intention to opt
out beforehand, and the Company identifies power to the device was cut using interval
meter data and device communication data, the Company has treated this as an opt-
out. The proposed tariff language is intended to add clarity around this point.
ADV 1 355/ Advice No. 21 -12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 12:
See page 8. ls the new installation fee cost-based?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. {2:
As background, the $500 installation fee was a tariff requirement prior to 2013. At that
time, the Company stopped adding new participating pump locations as a result of the
Settlement Agreement approved in Order No. 13-482 in Docket UM 1653 and
eliminated the installation fee language as it was no longer relevant.
!n preparation of the filing and in consideration of removing the marketing limitation, the
Company evaluated the average installation cost for new devices installed during the
2021 program season to validate if the $500 (as previously included in the tariff)
continued to be reasonable. The Company found the fee is approximately 88 percent of
the average installation cost of $566 for new devices installed during 2021.
With the proposed program being available to all potential customers and sizes of
pumps, the Company believes that offsetting most of the cost of the installation for the
smaller pumps (30 horsepower or less) is needed to help maintain cost-effectiveness of
the overall program. ldaho Power chose a single price approach that is simple to
understand, implement, and leaves the decision to participate with the customer rather
than having a minimum pump size participation restriction.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 13:
the new instatlation fee.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 13:
The Company did not prepare a workpaper for the proposed installation fee.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 14:
-The
Company did not consider proposing any rate design changes as part of
this advice filing. The Company believes it may be most appropriate to consider
modifications to the rate design structure when the overall cost-of-service for all
customer classes is reviewed.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 15
TOPTC OR KEYWORD: Demand Response tariff changes
value nces between DSM
that DSM only provides 55% as
the Company? ln your response
more to limitation in the number
the number of hours of DSM per day. !n your description please also indicate if
customer event opt outs are relevant.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. t5:
Th6TS"Z" Effective Load Carrying Capability ("ELCC") of Demand Response ("DR")
effectiveness compared to a Single-Cycle Combustion Turbine ("SCCT") was not a
surprise to the Company. The reduction is primarily due to a combination of the
seasonal limitations (60 hours, or 15 days, per season), the weekly limitations (3
weekdays per week), and the daily limitations (4 hours per day) of the DR programs. A
combustion turbine does not have these same limitations and can be utilized more
frequently, flexibly, and for longer periods of time, which directly corresponds with a
higher capacity value.
Customer opt-outs during demand response events were not specifically modeled in the
analysis used to determine the ELCC of the DR programs, but were incorporated as
explained in the response to Staffs lnformation Request No. 10.
TOPIC OR KEYWORD: Demand Response tariff changes
T 1
ne ,wo US
ELor decrease the sccr?
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
a load and resource balance year than
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 16:
-Generalty,
a load and resource balance year with more variable resources (such as
solar), willshift net peak load into later hours of the day compressing the net peak into a
smaller hourly time period. A compressed net peak makes Demand Response more
effective because the program's capacity can be dispatched to meet system needs
during a more consistent and defined timeframe. Therefore, ELCCsccr will increase with
a load and resource balance year that has more solar resources and will decrease in a
year where there are less solar resources.
ADV 1355/Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
e which hours was
the Was there de 1pm hours?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 17:
-ln
the Company's modeting, Demand Response ("DR") deployed throughout the entire
allowable range of the portfolio parameters (3:00pm to 11:00pm). The hours at which
DR was dispatched is dependent upon the test year utilized for the analysis.
The attachment to this response includes hourly megawatt DR dispatched for all 365
days when using Test Year 2 data.lt is important to note that (1) these specific results
only include ldaho Power's current solar resources plus the Jackpot solar project, and
(2) only one group is available for deployment during the 10:00pm to 1 1:00pm hour, as
the lrrigation Peak Rewards program is the only program that has a participation option
during that timeframe.
ADV 1355/Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. ,l8:
See Aftachment 2, page 1. \Mat is the planning horizon?
IDAHO POWER COTIPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 18:
ida-86-Power's lntegrated Resource Plan ('lRP') includes a planning period of 20 years.
This planning period is also referred to as the planning horizon and for the 2021 lRP,
the planning horizon spans from years 2021 to 2040.
ADV 1355/Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 19:
See Aftachment 2, page 2, which describes historical resource availability and statistical
forced outage rates. Please describe how actual historical performance of thermal
resources are used in the Company's ELCC model.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 19:
ifr-lhE-Company's Effective Load Carrying Capability model, data inputs for dispatchable
resources (the Hells Canyon Complex, coal plants, gas units, etc.) include monthly
capacities and their related Effective Forced Outage Rates ("EFOR"). For existing
dispatchable generation, monthly capacities and corresponding EFOR are provided by
the Company's Power Supply department. \Mren data is not available, EFOR values
from the Generator Availability Data System ("GADS") managed by the North American
Electric Reliability Corporation ('NERC") are utilized.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 20:
ad definition from? Do others use this
definition? Statistically, are there any times where there is simultaneously zero wind,
solar, PURPA resources, and run-of-river hydro generation on IPC's system?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 20:
The Company developed its'net load'definition for its Effective Load Carrying
Capability ('ELCC") analysis based on the general industry understanding that "net
load" is total system demand less non-dispatchable variable generation resources.
ldaho Power recognizes wind, solar, PURPA resources, and run-of-river hydro to fit
under the category of variable generation resources for its ELCC modeling purposes.
The Company's definition is not directly derived from another utility, and the Company is
unaware of whether another utility utilizes this exact definition for net load.
For the four years of historicaldata utilized in the Company's ELCC study, there is not
an occurrence where wind, solar, PURPA resouroes, and run-of-river hydro all
simultaneously have zero generation on Idaho Power's system.
TOPIC OR KEYWORD: Demand Response tariff changes
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
the are added and how this
by adding all the groups
me
works: "the a lastly creates aprocess
into a single load shape."
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUESTw!.:
\A/hen modeling Demand Response ("DR') in ldaho Power's Effective Load Carrying
Capability (.ELCC") model, the algorithm is designed to allow the user to set the DR
dispatch quantity, in megawafts ("MW') that can be applied per iteration. As described
in Attachment 2 to Tariff Advice No. 21-12, this was set to 50 MW per iteration.
\Nhen the algorithm identifies an hour within the program parameters that has a net load
above the set target set for a particular day, 50 MW of DR is applied to that hour on that
day. Once the algorithm has finished iterating over all hours in each day of the year, the
50 MW groups of dispatched DR are added to a DR shape. The DR shape will have
increments of 50 MW depending on how many groups were dispatched in a particular
hour. For example, if through the iteration process, four different groups were required
to dispatch on July 10th at 6:00pm to meet the day's target, the DR shape would have a
value of 200 MW for that particular hour:
il
DR Shapei= I DR GroupiMW
i=1
N is the total number of groups modeled. When this is completed for every hour of the
year, the combined DR group output makes up the DR dispatch pattern.
ADV 1 355/ Advice No. 21 -12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 22:
See Attachment 2, page 4. Please define'DR effectiveness" as used on the y-axis of
Chart 1.
NO. 22:
Demand Response ("DR") effectiveness is the amount of equivalent perfect generation
that has the same impact on reliability as the nameplate capacity of the DR portfolio.
The DR effectiveness on the y-axis divided by the DR Nameplate on the x-axis results
in the Effective Load Garrying Capability ('ELCC') of DR for that given nameplate
capacity.
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
, page the LOLP values pictured in Charts 2-5.|f
these values are normalized, please also provide the raw values
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.23:
FiEdEsee the attachment provided for this response. The requested Loss-of-Load
Probability values for the individual charts are separated by sheet. Al! four scenarios
use the month of July in Test Year #2:. No solar resources and no demand responseo 2020 solar resources and no demand response. 2023 solar resources and no demand responseo Future solar resources and no demand response.
ADV 1355/ Advice No. 21-12
Idaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 24:
to Chart 3. The scale of the y-axis has
the same label in both graphs and there is no indication of changes to the demand
inputs, so why does adding resources while holding demand constant increase loss of
Ioad probability? For example, why does Day 5, hour 21 change from blue to red
between Chart 2 and Chart 3?
NO. 24:
Tfr6ii6mand in the Effective Load Carrying Capability analysis was not held constant.
The demand was uniformly increased untilthe set reliability target was achieved. \Mren
adding variable resources such as solar, the increase in generation willcause the
demand to increase further from the previous case when the variable generation was
not on the system. Depending on the shape of the load and the resources included on
the system, the hours could potentially have different Loss-of-Load Probability values.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 25:
r whether there are any historical
correlations between thermal resources outages and peak net-need times in its EFORs
and monthly outage tables?
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.25:
N6li-h-e resources included in the outage table have the same probability of undergoing
a forced outage during all hours of the year. The thermal resources are given the same
Equivalent Forced Outage Rate value for the entire year. However, the monthly capacity
is adjusted depending on plant characteristics. For example, the monthly capacities of
the gas plants are reduced to consider the reduction in output due to ambient
temperatures. A conservative approach is used by setting the monthly capacity of the
power plant to the minimum generation output expected on a hot summer day.
A similar approach is used in hydrogeneration with storage, where the amount of water
available is taken into account to determine whether or not a generator failure in a plant
with multiple generation units would result in a loss of capacity.
TOPIC OR KEYWORD: Demand Response tariff changes
, page the dispatch
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
shapes are computed in
storage and DR are"dispatch shapes for energy-limited resources such as baftery
created based on net load."
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORIT'ATION REQUEST
NO. 26:
As described in Attachment 2, the Effective Load Carrying Capability of Demand
Response ("DR") was calculated using a multi-step process. First, every day in a test
year was sorted from highest to lowest based on their net peak load in megawatts
("MW'). Second, a daily MW target was set for each day based on the highest net load
hour within the day and the size of the dispatchable DR group. The Company
determined that an approximate 50 MW group size results in a capacity amount that is
operationally manageable yet still large enough to have a meaningfu! impact on
reducing system load. lt also most closely aligns with how ldaho Power's Load Serving
Operations group dispatches the programs.
For battery storage, the same basic algorithm was used with a couple differences. First,
the DR portfolio constraints were removed, and storage was allowed to be dispatched
every day of the year with no maximum number of events. Second, the MW of the group
was reduced to 1 MW, allowing the algorithm to dispatch the exact number of MW
required to maintain the net load under the daily target. This allows the algorithm to
capture the increased flexibility battery storage has over the DR programs.
ADV 1355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
STAFF'S INFORMATION REQUEST NO. 27:
eak pricing. Please describe generally if
IPC is underpricing its highest risk hours and if dynamic pricing is interchangeable with
DSM.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO.27:
Attachment 3 to Advice No. 21-12 shows the Northwest Power and Conservation
Council's assumptions on megawatt potential and program administrative costs. lt does
not relate to ldaho Power pricing or rates. The Company does not consider pricing
programs as interchangeable with either Energy Efficiency or Demand Response
("DR"), collectively referred to as Demand-Side Management. Although, pricing
programs are often categorized as DR due to similar program objectives, which is to
modiff customers usage or incentivize demand reduction over a short period of time in
response to an economic driver.
ADV 1355/Advice No. 21-12
Idaho Power Company's Responses to Staffs First Set of lnformation Request
!nformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
, page rs from 9-11 pm. Please confirm that
IPC thin ks there is a noteworthy risk
given that BPA defines Iight
ht Ioad hours are 10 p.m. to
after 1 opm Please provide some
"Times of
ofa
load
n outage
hours ascontext
BPA, Iig 6 a.m. Monday through
low electricity usage. For
Saturday and allday
Sunday."
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 28:i-n a system with a high penetration of solar photovoltaic ("PV'), supplying the peak load
hours (around 6:00pm) has a lower risk due to the abundance of resources that are
available during that timeframe. Meeting the net peak demand after sundown will be the
key challenge as the Company moves forward. The Company expects that with the
continued addition of solar PV, the risk associated with the 10:00pm to 11:00pm hour
will increase.
Regarding Bonneville Power Administration ("BPA"), it may be helpful to note that ldaho
Power's service area is almost entirely in the Mountain Time Zone. For example, sunset
on July 1 in Boise is only 33 minutes prior to sunset in Portland despite the hour time
zone difference. For ldaho Power's system, the sun goes down a little Iater than a
system in the Pacific Time Zone, whiih may resutt in'net peak Ioad extending into the
10:00pm to 11:00pm hour (Mountain Time).
ADV 1 355/ Advice No. 21-12
ldaho Power Company's Responses to
Staffs First Set of lnformation Request No. 1-29
TOPIC OR KEYWORD: Demand Response tariff changes
net demand hours for each of the last 5
years.
IDAHO POWER COMPANY'S RESPONSE TO STAFF'S INFORMATION REQUEST
NO. 29:FiEiEsee the attachment provided for this response.
BEFORE THE
PUBLIC UTILITIES COI'IMISSION OF OREGON
cAsE NO. ADVI3SS,ADVICE NO. 21-12
IDAHO POWER COMPANY
REQUEST NO. 1
ATTACHMENT NO. 1
IDAHO POVVER COMPANY FOUR+HfIEIIIREV|SED SHEET NO. 23-1
CANCELS
P.U.C. ORE. NO. E.27 THIRD FOURTH REVISED SHEET NO.2}1
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
PURPOSE
The lrrigation Peak Rewards Program (the Program) is an optional, supplementalservice that permits participating
agricultural irrigation Customers taking service under Schedule 24 to allow the Company to turn off specific irrigation
pumps with the use of one or more Load Control Devices. In exchange for allowing the Company to turn off specified
irrigation pumps, participating Customers will receive a financial incentive for load reductions during the calendar
moinths oi.tune, .tuly, an+Aigust,endScptembg for each metered service point (Metered Service Foint) enrolled G)
in the Program.
AVA!I.AB!LIry
Service under this schedule is available on an optional basis to Customers with a Metered Service Point or Points
receiving service under Schedule 24 where the Metered Service Point serves a water pumping or water delivery
systemusedtoirrigateagricuIturalcropsorpasturage.
eispagfOptien €)
The Company shall have the right to select and reject Program participants at its sole discretion based on criteria
the Company considers necessary to ensure the effective operation of the Program. Selection criteria may include,
but will not be limited to, Billing Demand, location, pump horsepower, pumping system conflguration, or electric
system configuration. Past participation does not ensure selection into the Program in future years. Participation
may be limited based upon the availability of Program equipment and funding.
Each eligible Customerwho chooses to take service under this optional schedule is required to enter into a Uniform
lrrigation Peak Rewards Service Application/Agreement (Agreement) with the Company prior to being served under
this schedule. The Agreement will grant the Company or its representative permission, on reasonable notice, to
enter the Customer's propefi to maintain one or more Load Control Devices on the electrical panel servicing the
irrigation equipment associated with the Metered Service Points that are enrolled in this Program and to alloiv the
Company or its representative reasonable access to the Load Control Device(s). By entering into the Agreement,
each Gustomer also agrees to not increase for the sole purpose of participating in the Program the capaci$,
horsepower (HP) or size of the irrigation system served by the Company.
PROGRAM DESCRIPTION
Service under this optional, supplementary Program permits the Company to turn off specified irrigation pumps for
a limited number of hours during the period of June 15 through nugu*Sgle11be1 15 (Program Season). The
Company will utilize dispatchable Load Control Devices to turn off specific irrigation pumps during Load Control
Events. !n limited applications, a select group of eligible Customers will be permifted to manually interrupt electric
service to participating inigation pumps during Load Control Events (See the Manual Dispatch Option). ln exchange
for allowing the Company to intenupt service to specified inigation pumps, participating Customers will receive a
financial incentive for usage that occurs during the calendar months of June, July, an4August-eld Septembg for
each Metered Service Point enrolled in the Program.
DEFINITIONS
(eQ)
Bill Credit. The Bill Credit is the sum of the Demand Credit and the Energy Credit applied to the Customer's monthly
bills for usage that occurs during the calendar months of June, July, an4August-elCjCptembel of each calendar
year. This amount may be prorated for the number of days during the months of June, July,-anC August, and
September that fall in the Customer's billing cycle to correspond with the Program Season. The Bill Credit amount
may be applied directly to participating Customers' bills or provided in the form of a check.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise,ldaho Effectivewith Service
Rendered on and after:
Advice No.15 1'lt1-12
(c)
Ia
|DAHO POWER COMPANY FoURr++EIEIIIREVTSED SHEET NO.23-2
CANCELS
P.U.C. ORE. NO. E.27 THREFOURTH REVISED SHEET NO. 2}2
SCHEDULE 23
I RRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
DEFINITIONS (Continued)
Demand Credil. The Demand Gredit is a demand-based financial incentive provided in the form of a credit on the
monthly billfor the Metered Service Point enrolled in the Program. The monthly Demand Credit is calculated by
multiplying the Program kW by the demand-related incentive amount for the lnterruption Option selected by the
Customer. The Demand Credit will be included on the Customer's monthly bills for usage that occurs during the
calendar months of June, July, anC-August-_aldjeptembeI of each year. This amount may be prorated for the
number of days during the months of June, July, an4August-sld$eptembel that fall in the Customer's billing cycle
to conespond with the Program Season.
Demand Energy Credit = Program kW x demand-related incentive amount
Enerov Credit. The Energy Credit is an energy-based financia! incentive provided in the form of a credit on the
monthly billfor the Metered Service Point enrolled in the Program. The monthly Energy Credit is calculated by
multiplying the Program k\Mr by the energy-related incentive amount for the lnterruption Option selected by the
Customer. Customers identified to have an out-ofdemand season billinq cycle will receive onlv an out-of-demand
season enerov credit for the apolicable billino period. The Energy Credit will be included on the Customer's monthly
bills for usage that occurs during the calendar months of June, July, andiugust-elld.$eptembel of each year. This
amount may be prorated for the number of days during the months of June, July, andAugust, an9!_1$eg!ember -that
fall in the Custome/s billing cycle to correspond with the Program Season.
Energy Credit = Program k\Mr x energy-related incentive amount
Load Control Device. Load Control Device refers to any technology, device, or system utilized under the Program
to enable the Company to initiate the Load Control Event.
Load Control Event. Refers to an event under the Program where the Company requests or calls for interruption
of specific irrigation pumps either manually or with the use of one or more Load Control Devices.
Nominated Demand. Nominated Demand is the amount of demand that participants under the Manual Dispatch
Option must declare as av€ilableplanned to be ava during Load Control Events.
Notification of Prooram Acceotance. An interested Customer must sign and return to the Company an Agreement
speciffing the Metered Service Point(s) to be included in the Program. lf a Customer is selected for participation in
the Program, a notification of acceptance into the Program will be mailed to participants, which will include a listing
of the Metered Service Point(s) that have been enrolled.
Prooram kW. The Program kW is the demand amount, as measured at the Customer's meter in kilowatts (kW)
associated with the aoplicable billinq period, @hat is multiplied by the applicable
incentive amount to determine the Demand Credit under the Automatic Dispatcheaeh lnterruption Option. Under
the Manual Dispatch lnterruption Option. the Prooram kWwillbe based upon the maximum measured intervalkW
durino the 24-hour period precedinq 8:00 A.M. MDT the dav of the announcement of a Load Control Event. minus
the averaqe interval kW durino an event.
Prooram k\Mr. The Program kWh is the energy amount, as measured at the Customer's meter in kilowatt-hours
(k\Mr) associated with duingrthe applicable billinq periodPr€gFam-Season, that is multiplied by the applicable
incentive amount to determine the Energy Credit under each lnterruption Option.
Prooram Season. The Program Season is the period June 15 through nusust$eple!0bel15 of each year.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and afier:
Advice No.15 11t1-12
(g)
G)
IN)
G)(g)
(])
(c)
IN)
(eN
)
IDAHO PO\ /ER COMPANY SsUer+Elrr[REVtSED SHEET NO.23-2
CANCELS
P.U.C. ORE. NO. E.27 THRTFOURTH REVISED SHEET NO.2}2
Variablc Enercv e
Scrviec Peint enrelleC in the Pregram, The Variablc Sncrgy ereCt ie ealeslateC by multiplying Variable Prcgnm
t+eerrespend with the Pregram Seaeen, The Variable Energy ereCit Cees net apply te the first three tead Gentrel
Event+
Variable Energy Credit - Variable Pregram k\Ml x variable energy relateC ineentive ameunt
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, Idaho Effective with Service
Rendered on and afrer:
Advice No.l*144-12
I DAHO PO\A'E R COM PANY FOUR+TIEIEITTREVIS ED SH EET NO. 23.3
CANCELS
P.U.C. ORE. NO. E-27 THIR}FOURTH REVISED SHEET NO.2}3
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
DEFINITIONS (Continued)
kWtr bv the enerov-rel Variable
Enerov Credit is paid in the form of a check no later than 70 davs after the Prooram Season. The Variable Enerov
Credit does not applv to the first four Load Control Events.
Variable Enerqv Credit = Variable Proqram kVVh x variable enerov-related incentive amount
VariableProqramkWt.TheVariableProgramkWtisthedemandamount@,as
measured at the Customer's meter in kilowatts (kW) multiplied by the hours of interruption for the Metered Service
Point for each Load Control Event@. The Variable Program k\Mt is multiplied by the
applicable variable incentive payment to determine the Variable Energy Credit under each lnterruption Option.
Variable Program k\Mr = metereAPpsram kWx hours of interruption for each Load Control Event-€lu+ingFPr€g+am
Seasen
INTERRUPTION OPTIONS
Under the lnterruption Options, the Company will dispatch remotely service interruptions to specified
irrigation pumps any Monday through Saturday during the Program Season between the hours of 4!:00
P.M. and 8l!:00 P.M. Mountain Daylight Time (MDT), excluding holidays (Standard lnterruption).
Customers may elect to participate until 9![:00 P.M. MDT (Extended lnterruption) and wi]l receive a larger
Variable Energy Credit. Service interruptions may last up to 4 hours per day and will not exceed 15Q hours
per calendar week and 60 hours per Program Season. During each Program Season the Company will
conduct a minimum of three Load Control Events. Customers participating in the Automatic Dispatch
Option may not receive advance notification of a Load Control Event, but will be notified after the Load
Control Event begins. Customers participating in the Manual Dispatch Option will receive advance
notification at Ieast 4 hours prior to a Load Control Event. The Company will provide notice of a Load
Control Event via the following communication technologies: telephone, e-mail and/or text message. lf
prior notice of a pending Load Control Event has been sent, the Company may choose to revoke the Load
Control Event and will provide notice to Customers up to 30 minutes prior to the Load Control Event.
Customers who elect to participate in the Program may be eligible for one of the following lnterruption
Options:
Automatic Disoatch Ootion. A dispatchable Load Control Device will be connected to the electrical
panel(s) serving the irrigation pumps associated with the Metered Service Points enrolled in the
Program. The Load Control Device utilized under the Automatic Dispatch Option will provide the
Company the ability to send a signalthat will interrupt operation or not allow the associated irrigation
pumps to operate during dispatched Load Control Events. This option requires that all pumps at
the Metered Service Point be controlled.
Under the Automatic Dispatch Option, the Program kW will be based upon the monthly Billing
Demand, as measured in kW, forthe associated Billing Period, The Program k\Ml underthis option
will be based upon the monthly energy usage, as measured in k\A/h, for the associated Billing
Period.
lssued by IDAHO POWER COMPANY OREGONBy ,VicePresident, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No. a5la44
o!)
(Ml
t
Ie)
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(a)
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IDAHO POI/'J|ER COMPANY egUn+s-ElEEl-RB/tSED SHEET NO.23-3
CANCELS
P.U.C. ORE. NO. E.27 THTR}FOURTH RB/ISED SHEET NO.2}3
times per eeaeen prier te er during a tead Contrel Event, Eaeh time a eusbmer eheeses te ept
eut ef ene ef the three minimum tead Gentrel Events a fee ef $5-00 per kW will be aseeesed baeed
upen the eunent Billing Peried's kW, Eaeh time a eusbmer eheeees te ept eut ef a teaC Centrel
Event after the three minimum teaC Centrel Events a fee ef $1,00 per kW will be aseessed baseC
upen the eurent Billing Peried'e kW, The ept eut fee will net exeeed the tetal Bi[ ereCtr fer the
lssued by IDAHO POWER COMPAT{Y OREGONBy ,McePresident, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No.l$14.t;!
IDAHO POWER COMPANY EOUR+++FIFTH REVISED SHEET NO. 23-4
CANCELS
P.U.C. ORE. No. E-27 IFIIRD-FOURTH REVISED SHEET NO. 23-4
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTtoNAL)
(Continued)
INTERRUPTION OPTIONS (Continued)
Automatic Dispatch Option (Continued)
Each time a customer chooses to opt-out of one of the Load Control Events a fee of $6.25 per kW
will be assessed based uoon the current Billinq Period's kW. The opt-out fee will not exceed the
total Bill Credit for the Prooram Season. Anv oot-out fee will be apolied at the end of the Proqram
Season or after the apolicable billino cvcle closes. Opt-out fees mav be waived for circums_lanees
involvino planned or unplanned outaoes of 3 hours or more occurrinq within 24 hours of a Load
Control Event or a multidav outaoe within 72 hours of an event. At its discretion, the Comoanv mav
assess an opt-out fee should it be determined the participant overrode the command to the dispatch
device therebv allowinq the pump to run durino the load control event.
Manua! Disoatch Ootion. Customers are elioible to manuallv control Metered Service Points with
gj_at Ieast 1,000 cumulative HP, or Metered Service Points that have been determined by the
Company to be limited by load control device communication technology or installation
configuration; are eligible fer the Manual Dispateh Optien. Under the Manual Dispatch Option,
eligible Customers have the flexibllity to choose which irrigation pumps at a Metered Service Point
willbe interrupted during each dispatched Load Control Event. Customers electing this option must
notiff the Company of their Nominated Demand durinq the enrollment period prior to June 1 of
each year.
Customers@heManualDispatchoptionarerequiredtoprovidenoless
than their Nominated Demand during each Load Contro! Event. Each time a customer chooses to
provide less than their Nominated Demand during one of the three minirnum Load Control Events,
an opt-out fee of $5S06;25 per kW will be assessed on the Nominated Demand not made available
for interruption.
during a tead Centrel Event' after the three minimum tead Centrel Events; an ept eut fee ef $1,00
per fW witt Ue aesee he opt-
out fee will not exceed the total Bill Credit for the Program Season. Any opt-out fee will be applied
at the end of the Program Season or after the applicable billinq cvcle closes. Oot-out fees mav be
waived for circumstances involvinq planned or unplanned outaqes of 3 hours or more occurrino
within 24 hours of a Load Control Event or a multidav outaqe within 72 hours of an event.
Under the Manual Dispatch Option, the Program kWwill be based upon the maximum measured
interval demand during the 24-hour period preceding 8:00 A.M. MDT the day of the announcement
of a Load Control Event, minus the average demand during an event, as measured in kW over
applicable load profile metering intervals. This applies to each Load Control Event initiated during
a Billing Period. lf there are no Load Control Events during a Billing Period, then the Program kW
will be the Nominated Demand. The Program kWh under this option will be based upon a
calculated value, as measured in k\Mr. The Program k\Mt will be calculated separately for each
Billing Period by multiplying the monthly Program kW by the ratio of the monthly energy usage to
the Billing Demand for the associated Billing Period.
INCENTIVE STRUCTURE
lncentive payments under the lnterruption Options will be determined based on a fixed payment and a variable
payment. The fixed portion of the incentive payment will be paid through a Bill Credit and the variable portion will
be paid by check no more than 4570 days after the end of the Program Season. The first foUt+rce Load Control
lssued by IDAHO POWER COMPANY OREGONBy , Mce President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No.15 1lt1-12
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IDAHO POWER COMPANY FOURH+EIFT}|REVISED SHEET NO. 23-4
CANCELS
P.U.C. ORE. No. E-27 THIRBFOURTH REVISED SHEET NO. 23-4
Events will not be subject to the Variable Energy Credit. The variable payment wi!! be based on the number of
hours a participant's pump is interrupted during the Program Season and their associated Program kW after the
fi rst three-fgglLoad Control Events.
lssued by IDAHO POWER COMPANY OREGONBy , Mce President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Sheet, Boise, ldaho Effective with Service
Rendered on and afier:
Advice No.lSl44-12
lntor+us[i€,e€Eti€n
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ss,oo $0s076 $0,1-18 sol€8
IDAHO POWER COMPANY F€UR+!+EIEI}I-REVISED SHEET NO. 23.4
CANCELS
P.U.C. ORE. No. E-27 THIRIFOURTH REI/ISED SHEET NO. 23-4
lssued by IDAHO POVVER COMPAi.IY OREGONBy ,VicePresident, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, Idaho Effective with Service
Rendered on and after:
Advice No.15 11t'l-12
(N)
TDAHO POWER COMPANY FOUR++EIEIIIREVISED SHEET NO. 23-5
CANCELS
P.U.C. ORE. No. E.27 THIRD FOURTH REVISED SHEET NO.23-5
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
INCENTIVE STRUCTURE (Continued)
INSTALLATION FEES
An installation Fee of $500 will be reouired for anv new particioatinq Metered Service Point with
measured horsepower of 30 or less. The !nstallation Fee is non-refundable except when a Customer elects earlv
termination and prior to the installation of a load control device at their pump location.
TERM OF AGREEMENT AND TERMINATION
The term of the Agreement, as it applies to each Metered Service Point accepted for participation, shall commence
on the date the Agreement is signed by both the Customer and the Company and shall automatically renew on
March 15 of each calendar year unless notice of termination is given by either party to the other prior to the annual
renewal date or unless othenrise terminated as follors:
A Customer may terminate the participation of a Metered Service Point and avoid the Termination Fee by
notifying the Company or its representative before the Program Season.
A Customer who terminates the participation of a Metered Service Point anytime between June 15 and
n{rgu6t$Cp!e!&el15 of each calendar year shall pay the Company a Termination Fee., This fee. whi€h
sum will be included on the Customer's monthly billfollowing termination of participation. The Custome/s
Bill Credit shall be prorated for the number of days in that month the Customer satisfactorily participated in
the Program. Upon terminating participation of a Metered Service Point under the provisions of item 2, the
Customer may not re-enrollthe Metered Service Point into the Program untilthe following calendar year
and the applicable Termination Fee has been paid in full.
Termination Fees:
3.
Automatic Dispatch Option: $500.00 per Metered Service Point terminated under item 2
lf there is evidence of alteration, tampering, or othenrvise interfering with the Company's abili$ to initiate a
Load Control Event at a Metered Service Point, the Agreement as it applies to that Metered Service Point
will be automatically terminated. !n addition, the Customer will be subject to each of the following:
a. The Customer will be required to reimburse the Company for the cost of replacement or repair of
the Load Control Device(s), including labor and other related costs.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No. 15 1'lu 1-12
1
2.G)
(
M
)
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)
Extended
lnterruotion
Variable Enerqr
Credit
($ per Variable
Prooram kWh)
Demand Credit
($ per Proqram kW)
Enerov Credit
($ per Proqram kwh)
Enerqv Credit ($
per Proqram kwh)
for Out-of-
Demand Season
Billino Cvcles
Standard
lnterruption
Variable Enerov
Credit
($ per Variable
Proqram kVVh)
$5.25 $0.008 $0.021 $0.18 $0.25 I:
(1rI)
T
IDAHO POWER COMPANY FOIJRT}+EIEHREVISED SHEET NO.23-5
CANCELS
P.U.C. ORE. No. E-27 THIRIFOURTH REVISED SHEET NO. 23-5
b, An applieable Terminatien Fee; as previCed unCer item2' will be applied te the Custemer's menthly
ie+
e fne eempany witt r
Custemer's menthly bill(s) fer the Metered Serviee Peint as a result ef the Cuetemer'e partieipatien
Nete; A serviee diseenneetien fer any reasen deee net terminate the Agreement,
SPECNT EONDITIONS
The previeiene ef thi+eehedule de net apply fer any time peried that the Cempany utilizes a tead Centrel Deviee
i
will net affeet the ealeulatien er rate ef the regular Servieet Energy er Demand eharges aeseeiated with a
Custerner'e standard serviee sehedule,
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and afier:
Advice No. lS 1'l^1-12
TDAHO POWER COMPANY FOURI++EIEIIIREVTSED SHEET NO. 23-6
CANCELS
P.U.C. ORE. No. E-27 THIRD FOURTH REVISED SHEET NO. 23-6
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
TERM OF AGREEMENT AND TERMINATION (Continued)
Termination Fees: (Continued)
b. An applicable Termination Fee, as provided under item 2, will be applied to the Customer's monthlv
bill followino the termination of participation.
c. The Companv will reverse anv and all Demand Credits and/or Enerqv Credits applied to the
Customer's monthlv bill(s) for the Metered Service Point as a result of the Customer's participation
in the Prooram durino the current vear.
Note: A service disconnection for anv reason does not terminate the Aoreement.
SPECIAL CONDlTIONS
The provisions of this schedule do not apolv for anv time period that the Companv utilizes a Load Control Device
installed under this Proqram to interrupt the Customer's load for a svstem emerqencv in accordance with NERC
standards. ldaho Power's Rule J. or anv other time that a Customer's service is interrupted bv events outside the
control of the Companv. The provisions of this schedule will not affect the calculation or rate of the reqular Service,
Enerqv or Demand Charoes associated with a Customer's standard service schedule.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No. 15 14''l-12
(N)
IN)fvl)
IDAHO POWER COMPANY FOUR+H-EIEIH-REVISED SHEET NO. 236
CANCELS
P.U.C. ORE. No. E-27 THIRDFOURTH RB/ISED SHEET NO. 23-6
IDAHO POWER COMPANY
Uniform lrrioation Peak Rewards Service
Aoolicatio n/Aoreement
THIS AGREEMENT Made this _ day of ,20-between
hereinafter called Customer, whose
billing address is and IDAHO PO\,\,ER
COMPANY, a corporation with its principal office located al1221West ldaho Street, Boise, ldaho, hereinafter called
Company. This Agreement shall automatically renew on March 15 of each calendar year unless notice of
termination is given by either party to the other prior to the annual renewal date. This Agreement is for the Metered
Service Point(s) identified on the attached worksheet (Worksheet):
The Customer designates the folloring person as the Gustomer's authorized contact:
Authorized Contact:
CellPhone:
NOW, THEREFORE, The Parties agree as follows:
The Uniform lrrigation Peak Rewards Service Application/Agreement must be signed by the
Customer and the Customer must be the person who is responsible for paying bills for retail electric
service provided by the Company at the Metered Service Point(s) identified on the Worksheet.
We*eneet is laseC en
Bill CreCit eetimetee are previCeC fer illuetratien purpeeee, The euetemer agtreee te epedff whieh
MetcreC Serviee Peint(e) lietcC cn the Werkeheet the euebmcr wichee te enrell in the Pregram
iee
Peinte enrelleC inthe Mancal Di€fabh eptien the Custemer mcet netify the Cernparry ef NeminateC
gempanyr tne ec€to
ipi*
@
lssued by TDAHO POWER COMPANY OREGONBy , McePresident, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No. aSlaffi.
4)0
(D)
1
([4)
TDAHO POWER COMPANY FOUR+++EIEIII_REVISED SHEET NO. 23-7
CANCELS
P.U.C. ORE. No. E-27 THIRSFOURTH REVISED SHEET NO.23-7
SGFIEBTJIE23M
PRO|oRAM
(oP+roNAt)
(€€ntin+'€C)
W
ffi
on tne Worfsnea is Ua
Creait amounts are e ice
Point(st soecifieO
an estimatea eillC
fne eill Credit estl
wnicn UetereO Service P
Prooram anO tne tnter
MetereO Service Point
Comoanv ot ltominate
g. From time to time
Comoanv. tne Custo
orooertv on wnicn ttle
reoresentative to in
oanettnat servie in_in
otace on tne Custom
specincattv reouests r
4.The Customer understands and acknowledges that by participating in the Program, the Company
shall, at its sole discretion, have the ability to interrupt the specified irrigation pumps at the Metered
Service Point(s) enrolled in the Program according to the provisions of the lnterruption Option
selected. The Company retains the sole right to determine the criteria underwhich a Load Control
Event is scheduled for each Metered Service Point. The Customer also understands and
acknowledges that if a Metered Service Point provides electricity to more than one irrigation pump,
each pump will be scheduled for service intenuption simultaneously, excluding Metered Service
Points participating in the Program under the Manual Dispatch Option.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23,2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No.ls-4421:12
IDAHO POWER COMPANY FOUR+HTIFTIIREVISED SHEET NO. 23-7
CANCELS
P.U.C. ORE. No. E-27 THIRD-FOURTH REVISED SHEET NO. 23-7
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(OPTIONAL)
(Continued)
IDAHO POIIIER COMPNNV
Uniform lrdoation ice
Aoolicatio r/Aoreement
Gontinue0
5.For the Customer's satisfactory participation in the Program, the Company agrees to pay the
Customer the Demand Credit and/or Energy Credit conesponding to the Interruption Option
selected by the Customer. The Bill Credit included on the Worksheet is based upon the billing
history for the Metered Service Point(s) specified on the Worksheet, for the months of June, July,
and August, and_Septembel of the prior year. The Bill Credit will be paid in the form of a credit on
the Custome/s monthly bill or provided in the form of a check. The Demand Credit may be prorated
for the months of June, July, anC-August. and Seotember depending on the Customer's billing
cycle.
Metered Service Points participating under the Manual Dispatch Option, will receive a Bill Credit
from the Company within 30 days of billing due to the extensive data analysis required to process
interval metering data. Anv aoplicable Variable Enerqv Credits will be paid bv check no more than
70 davs after the end ofthe Proqram Season.
lf the Customerterminates this Agreement anytime between June 15 and Augsslseplember 15 of
the current calendar year while the Metered Service Point(s) are still connected for the Customer
may not re-enrollthat Metered SeMce Point into the Program untilthe following calendaryear and
the applicable Termination Fee has been paid in full.
7, lf there ie eviCenee ef afteratienr tarnpering; er etherwiee interfering wfrh the €empany'e ability te
i
lssued by IDAHO POWER COMPANY OREGONBy , Mce President, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No.lSl4M
1c)
(e)
IN)
(e)
6.
(M)
|DAHO POWER COMPANY ezuer+ElEI!_REVTSED SHEET NO. 23-8
CANCELS
P.U.C. ORE. No. E.27 THIRDFOURTH REVISED SHEET NO. 23.8
SEF}EDULE23
IRRIGATION PEAK R
PRO€.RAM
pPTroNAt)
€entinueA)
M
Uniferm lrrisatien Peak
Appli€ati€n/Aqrc€m€nt
€e*inuea)Z. f tnere is eviaenc
initiate a t-oad Con
MetereO Service Point
reimUurse tne Comoa
incluOino laUor an
sum_luill be included on
CreOits applieO to th
Customer's oarticb
g. The Companv's Sc
Ue consiaereO oart of t
This Agreement and the rates, terms and conditions of service set forth or incorporated herein and
the respective rights and obligations of the Parties hereunder shall be subject to valid laws and to the
regulatory authority and orders, rules and regulations of the ldaho Public Utilities Commission and
such other administrative bodies having jurisdiction.
10.Nothing herein shall be construed as limiting the ldaho Public Utilities Commission from changing any
terms, rates, charges, classification of service or any rules, regulations or conditions relating to service
under this Agreement, or construed as affecting the right of the Company or the Customer to
unilaterally make application to the Commission for any such change.
11 ln any action at lau or equity under this Agreement and upon which judgment is rendered, the
prevailing Party, as part of such judgment, shall be entitled to recover all costs, including reasonable
attorneys fees, incuned on account of such ac{ion.
lssued by IDAHO POWER COMPANY OREGONBy , Vice President, RegulatoryAffairslssued: @
23.2021
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No.151421-12
(€)
€)
M
(tvr)
9.
IDAHO POWER COMPANY FOURTH REVISED SHEET NO.23 8
P.U.C. ORE. No. E-27 THIRBORIGINALREVISED SHEET NO.23€9
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(OPTIONAL)
(Continued)
IDAHO POWER COMPANY
Uniform lrrioation Peak Rewards Service
Apo licati o n/Aq reement
(Continued)
12.The Company retains the sole right to select and reject the participants to receive service under
Schedule 23. 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.
13.Under no circumstances shallthe Company or any subsidiary, affiliates or parent Company be held
liable to the Customer or any other pafi for damages or for any loss, whether direct, indirect,
consequential, incidenta!, punitive or exemplary resulting from the Program or ftom the Custome/s
participation in the Program. The Customer assumes all liability and agrees to indemniff and hold
harmless the Company and its subsidiaries, affiliates and parent company for personal injury,
including death, and for property damage caused by the Gustomer's decision to participate in the
Program and to reduce loads.
14.The Company makes no wananty of merchantability or fitness for a particular purpose with respect
to the Load Control Device(s) and any and all implied warranties are disclaimed.
(APPROPRTATE STGNATURES)
Issued by IDAHO POWER COMPANY OREGON
By Gregeef#aidTimothv E. Tatum, Vice President, Regulatory Affairslssued: Deeembe+-3$-*OlSNovember
23.2021
1221 West ldaho Street, Boise, Idaho Effective with Service
Rendered on and after:
Advice No. 15 1'lt1-12 F€b+uaryJ5r20{€Februarv 15,2022
(€)
{€)
(M)
(M)
BEFORE THE
PUBLIC UTILITIES COMMISSION OF OREGON
CASE NO. ADV13ss/ADVICE NO. 21.12
IDAHO POWER COMPANY
REQUEST NO. 1
ATTACHMENT NO.2
IDAHO POWER COMPANY +CTRIEoUEIIREVTSED SHEET NO. 7+1
CANCELS
P.U.C. ORE. NO. E-27 SEEoII}THIRD REVISED SHEET NO.74.1
SCHEDULE 74
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(oPTtoNAL)
PURPOSE
The Residential Air Conditioner Cycling Program is an optional, supplemental service that permits participating
residential Customers an opportunity to voluntarily allou the Company to cycle their central air conditioners with
the use of a direct load control Device installed at their residence. Customers will receive a monetary incentive
for successfully participating in the Program during the Air Conditioning Season.
DEFINITIONS
AC Cvclino is the effect of the Company sending a signal to a Device installed at the Custome/s residence and
instructing it to cycle the Central Air Conditioning compressor for a specified length of time.
Air Conditionino Season is the period that commences on June 15 and continues through AuguetSeptembet 15 of (Q)
each calendar year.
CentralAir Conditionino is a home cooling system that is controlled by one or more centrally located thermostats
that controls one or more refrigerated air-cooling units located outside the Custome/s residence.
Cvclinq Event is a period during which the Gompany sends a signal to the Device installed at the Customer's
residence, which instructs the Device to begin AC Cycling.
Device is a direct load control device installed at a Customer's residence that enables the Company to conduct
AC Cycling.
Notification refers to the Custome/s indication of intent to initiate or terminate participation in the Program by
either contacting the Company's Gustomer Service Center, providing written notice or submitting an electronic
Application via the Company's website.
Oot Out is the term used to describe the two times each Air Conditioning Season in which the Customer may
choose to temporarily not participate in AC Cycling by providing advanced Notification to the Company.
Prooram Ooeration Area describes the area in which the Program will be offered to Customers and is comprised
of the Company's service territory within the State of Oregon where the infrastructure required to support AC
Cycling has been installed and is operational.
AVAILAB!LITY
Service under this schedule is avaihbb on an optional basis to Customers taking service under Schedules 1 and $)
5 who have Central Air Conditioning located at their residences and live within the Program Operation Area. (}J)
Customers may request to be added to the Program at any time during the year by providing Notification to the
Company.
Service under this schedule may be limited based upon the availability of Program equipment and/or funding.
The Company shall have the right to select and reject Program participants at its sole discretion based on criteria
the Company considers necessary to ensure the effective operation of the Program. Selection criteria may
include, but will not be Iimited to, energy usage, residential location, size of home, or other factors. Customers'
Central Air Conditioning equipment must be fully functiona! and comply with the National Electric Code (NEC)
stiandards. Customers who are renting or leasing their home must provide to the Company written proof of the
express permission of the owner of the Central Air Conditioning system prior to acceptance into the program.
lssued by IDAHO POWER COMPANY
By Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
OREGONlssued:@
Effective with Service
Rendered on and after:@I Ravice No._J€rOE21-12
I DAHO PO\ /ER CO M PANY SEeO+.IBJ FIBD_REVI SED SH EET NO. 7 4-2
CANCELS
P.U.C. ORE. NO. E.27 FIRSLSECOND REVISED SHEET NO.74.2
SCHEDULE 74
RESIDENTU\L AIR CONDITIONER
CYCLING PROGRAM
(oPTroNAL)
(Continued)
€)
1
TERMS AND CONDITIONS
Upon acceptance into the Program, Customers will be subject to the following terms and conditions:
Each eligible Customer who chooses to take service under this optional schedule is thereby giving the
Company or its representative permission, on reasonable notice, to enter the Customer's residence or
propefi to install a Device and, in certain cases, eilher a mass memory meter or an end-use meter and
to allow ldaho Power or its representative, with prior notice to the Customer, reasonable access to the
Device or other Program-related equipment follonting its installation.
Customers added to the Program during the Air Conditioning Season must be effectively participating in
the Program prior to the 20h day of the month in order to receive an incentive payment for that month.
A Customer may Opt Out of the Program two times during the Air Conditioning Season.€)
A Gustomer may discontinue participation in the Program without penalty by providing Notification to the
Company.
lf there is evidence of alteration, tampering, or othenrise interfering with the Company's ability to initiate a
Cycling Event, the Customer's participation in the Program will be terminated and the Customer will be
required to reimburse the Company for the cost of replacement or repair of the Device or other Program
equipment and the Company will reverse any amounts credited to the Customer's bills during the past
twelve months as a result of the Custome/s participation in the Program.
PROGRAM DESCRIPTION
1 At the Company's expense, the Company or its representative will install a Device at the Custome/s
residence.
2.A financial incentive of $5.00 per month for each of the three-&ulmonths June, July, and-August-_and
September will be paid to each Customer who successfully participates in the Program. This incentive
will be paid in the form of a credit on the Customer's monthly bil! for each month that the Customer
successfully participates in the Program, beginning with the July bill and ending with the
SeptemgeraElghg bill. lncentive payments are limited to one controlled CentralAir Conditioning unit per
metered service point. Customers who have more than one CentralAir Conditioning unit at a metered
service point may participate in the Program. A Device must be installed at each CentralAir Conditioning
unit. However, no additional incentive will be paid.
The Company will send a signalto the Device to initiate a Cycling Event. A Cycling Event may be up to
four hours per day on any weekday during the Air Conditioning Season, excluding holidays. A Cycling
Event may occur over a continuous 4-hour period or may be segmented throughout the day at the
Company's discretion in order to optimize available resources. Cycling Events may occur up to 15Q hours
each week and will not exceed a total of 60 hours per Air Conditioning Season. During each Air
Conditioning Season, the Company will conduct at least three Cycling Events. Mass memory meters or
end-use meters may be installed on some Customers' residences or Central Air Conditioning units for
program evaluation purposes. The residences or CentralAir Conditioning units selected for installation of
the meter shall be at the Company's sole discretion.
lssued by IDAHO POWER COMPANY OREGONBy , Mce President, Regulatory Affairslssued:
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:
Advice No._13-{521-12
2.
3.
4.
5.
(a
(c)
(C)
(c)
(c)
(c)
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3.
IDAHO POVTER COMPANYWSTED SHEET NO. 7,f-2
CANCELS
P.U.C. ORE. NO. E-27 F|RS+SECONDFE14SEDSHEETNO. T4-2
lssued by IDAHO PCIVI|ER COMPANY
Ay
1221 lrVost ldaho Strwt, Boiee,ldaho
Advlce No._J€-{521-12
OREGON
\fie Preaidcnt, Reguldory Affairslesued:
EfiEctircwith Seruie
Rendered on and frer:
IDAHO PO\ /ER COMPANY SECO!.IDI-IBD_REVISED SHEET NO. 74-3
CANCELS
P.U.C. ORE. NO. E-27 FIRST SECOND RH/ISED SHEET NO.74.3
SCHEDULE 74
RESIDENTIAL AlR CONDITIONER
CYCLING PROGRAM
(oPTroNAL)
(Continued)
(€)
SPECIAL CONDITIONS
The Company is not responsible for any consequential, incidental, punitive, exemplary or indirect damage to the
participating Customer or third parties that results from AC Cycling, from the Customer's participation in the
Program, or of Customer's efforts to reduce peak energy use while participating in the Program.
The Company makes no warranty of merchantability or fitness for a particular purpose with respect to the Device
and any and all implied warranties are disclaimed.
The Company shall have the right to select the AC Cycling schedule and the percentage of Customers' Central
Air Conditioning systems to cycle at any one time, up to 100%, at its sole discretion.
The provisions of this schedule do not apply for any time period that the Company interrupts the Customeds load
for a system emergency in accordance with or any other time that a (N)
Customer's service is interrupted by events outside the control of the Company. The provisions of this schedule
will not affect the calculation or rate of the regular Service or Energy Charges associated with a Custome/s
standard service schedule.
(D)
lssued by IDAHO POWER COMPANYBy,
1221 West ldaho Street, Boise, ldaho
Advice No. -13-{€21-12
OREGON
Vice President, Regulatory Affairslssued:
Effective with Service
Rendered on and after:
ebruarv 15,2022
BEFORE THE
PUBLIC UTILITIES GOMMISSION OF OREGON
CASE NO. ADVl3ss/ADVICE NO. 21.12
IDAHO POWER COMPANY
REQUEST NO. 1
ATTACHMENT NO.3
IDAHO PO\,\'ER COMPANY FIRS+gECONq REVISED SHEET NO.76-1
CANCELS
P.U.C. ORE. NO. E.27 ORICI}IALFIRST SHEET NO.7&1
SCHEDULE 76
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,
an4Aug ust-end Jgplembel.
AVAILAB!LITY
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 specif,ing the Facili$ Site(s) to be enrolled in the Program. To enroll in the Program,
Customers must be capable of providing a minimum Ioad 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, an4August, and
September. dDuring these-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.
Aooreoated Ootion. 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.
Business Davs. Any day Monday through Friday, excluding holidays. For the purposes of this Program,
lndependence Day ieand_Labg_89:r are the only holidayg during the Program Season. lf lndependence Day falls
on Saturday, the preceding Friday will be designated the holiday. If lndependence Day falls on Sunday, the
following Monday will be designated the holiday.
(c)
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lssued by IDAHO POWER COMPANY
By Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
OREGONlssued:W,_lo1€,2021
Effective with Service
Rendered on and after:
F ebruaN 1 5. 2022Fdbruery1r2017I eOviceNo.2l-12-16-15
IDAHO PO\A'ER COMPANY FIRST REVISED SHEET NO.76-2
CANCELS
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO.76-2
SCHEDULE 76
FLEX PEAK
PROGRAM
(oPTroNAL)
(Continued)
DEFINITIONS (Continued)
'Day of Load Adiustment. The difference between the average-Original Baseline kW and lhg av€\tage
actual metered kW during the $np-houre prior to the Participant receiving notification of an event. Scalar values
will be calculated bv dividinq the Oriqinal Baseline kW for each Proqram Event hour by the Baseline kW of the
hour preceding the event notification time.
Pregram Event is ealled, This adjuetment will be eapped at 20 pereent belew er abeve th€ Original Baeeline kW,
The scalars are multiolied bv the actual event dav kW for the hour precedinq the event notlfication time to create
the Adiusted Baseline kW from which load reduction is measured. The Adiusted Baseline kW for each hour
cannot exceed the maximum kW amount for anv hour from the Hiohest Enerov Use Davs or the hours durino the
event dav prior to event notification.
ie
ive
Event Availabilitv Time. Between 23:00 p.m. and 8l!:00 p.m. Mountain Daylight Time (MDT) each
Business Day.
Facilitv Site(s). AII or any part of a Participant's facility or equipment that is metered from a single service
location that a Participant has enrolled in the Program. For those Participants who have enrolled under the
Aggregated Option, Facility Site will refer to the combination of individual Facility Sites selected for inclusion
under the Aggregated Option.
Fixed Caoacitv Pavment. The Weeklv Effective kW Reduction multiplied bv the Fixed Capacitv Pavment
rate (as described in the lncentive Structure section). Participants are paid based on the averaqe event kilowatt
reduction.
Hiohest Enerov Usaoe Davs. The three days out of the immediate past 10 non-event Business Days that
have the highest sum Alelaver€g€ kW as measured across the Event Availability Time.
Hours of Event. The timeframe when the Program Event is called and Nominated kW is expected to be
reduced. The Hours of Event will not be less than two hours and will not exceed four hours.
Nominated kW. The amount of load expressed in kW that a Facility Site commits to reduce during a
Program Event.
Nominated kW 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 total Nominated kW lncentive Adjustment will not exceed the total incentive
amount for the Program Season (as described in the lncentive Structure section).
Notification of Prooram Acceotance. Wriften confirmation from the Company to the Participant. The
Notification of Program Acceptance will confirm each Facili$ Site enrolled in the Program, as well as the
Nominated kW amount for each Facility Site.
Issued by IDAHO POWER COMPANY OREGONBy , Vice President, Regulatory Affairslssued:
1221 West ldaho Street, Boise, ldaho Effective with Service
Rendered on and after:AdviceNo.lS-0321-12 @
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IDAHO POVVERCOMPANY FIRST REVISED SHEET NO. 7&2
CANCELS
P.U.C. ORE. NO. E-27 ORlcltlAL SHEET NO.7&2
Orioinal 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_hoUf.
lssued by IDAHO POWER COMPANY OREGONBy , Mce President, Regulatory Affairslssued:
1221 West ldaho Street, Boise, ldaho Efiective with Service
Rendered on and after:AdviceNo.{€-0321:12 @
G)
IDAHO POIA'ER COMPANY FIRST REVISED SHEET NO.76-3CANCELS_
P.U.C. ORE. NO. E.27 ORIGINAL SHEET NO.76-3
SCHEDULE 76
FLEX PEAK
PROGRAM
(oPTroNAL)
(Continued)
The folloring table provides an example of the calculation of the Original Baseline kW between hours of 32:00 (Q)
p.m. and l_08:00 p.m. using the (3) Highest Energy Usage Days of 5, 7, and 9.
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(NXC)
(NXC)
IN)
Participant. Any Gustomer who has a Facility Site that has been accepted into the Program
Prooram Apolication. Written form submitted by a Customerwho requests to enrolla Facility Site in the
Program.
Prooram Event. A time period when the Company requests or calls for reduction of the Nominated kW.
Prooram Season. June 15s through Augustsgptembq 15h of each year.
Prooram 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 thr€efoq Program
Events.
Variable Enerov Pavment. An enerqv-based financial incentive orovided to the Participant The oavment
is calculated bv multiplvino the Variable Prooram kWh bv the Variable Enerov Pavment Rate (as described in the
lncentive Structure section). The Variable Enerqv Pavment does not apolv to the first four Prooram 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 equa! the Nominated kW for
that Program Week.
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lssued by IDAHO POWER COMPANY
By Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
OREGON
lssued:
Effective with Service
Rendered on and after:
F ebruaw 1 5. 20221dppt1-2Hs
3:!€4 Pil 34-45 Pm 4ffi PM 56€7 Pil 67+8 PM 78€9 PM
Sum
-UsageTotal
Day
9-1oPM
(kwt
1
2
3
4
3000
3200
3100
3250
3100
3100
3200
3400
3000
3200
3'100
3300
3200
3200
3100
3400
3000
3100
3200
3300
3200
3300
3100
3400
3150
3300
3200
308321050s*ru.
313322000
3100 3000 3200 3100 3100 32006
3200 3300 3300 3300 32003300
3300 3300 3200 3200 3200 3300 3p/B22750103250
Orlgina!
Baseline
(kuv)3367 3400 3350 3367 3433 3400 3317
I AOvice No._{5-0321:12
lDAtlO PO\rtER COMPAIIY FIRST REVISED SHEET NO 7ffiG,ANCEL$-
P.U.C. ORE. NO. E-27 ORlGllrlAL SHEET NO. 764
ls6rd by IDAIIO POt TER COMPAiIY
By Grryry W. Said, Vm Prerldm( RegulatoryAfiairr
1221 lrl&st ldaho Strcet, Boise, ldalro
OREGON
lasued:
Efrc|rreuuiilt Serybe
Rendercd on and fficr:
Februar 15.2022llqH#I eorie No. -ts4o2t-12
IDAHO POVVER COMPANY FIR$-SECOND-REVISED SHEET NO. 76-4
CANCELS
P.U.C. ORE. NO. E-27 eRgSlAtFlRST SHEET NO.76.4
SCHEDULE 76
FLEX PEAK
PROGRAM
(oPTroNAL)
(Continued)
PROGRAM EVENTS
The Company wil! dispatch Program Events on Business Days during the Program Season between the
hours of 23:00 p.m. and 8l!:00 p.m. MDT. Program Events will last between two to four hours per day and will
not exceed 156 hours per calendar week and 60 hours per Program Season. During each Program Season the
Company will conduct a minimum of three Program Events. Participating Customers will receive advance
notification at least t^refog hours prior to the Program Event. The Company will provide notice of a Program
Event via the following communication technologies: telephone, text message, and e-mail to the designated
contact(s) submitted by the Participant in the Program Application. If prior notice of a pending Program Event has
been sent, the Company may choose to revoke the Program Event initiation and will provide notice to Participants
no less than 30 minutes prior to the Program Event.
REQUIREMENTS OF PARTICIPATING FACILITIES
Participants will have the flexibility to choose what equipment will be used to reduce the Nominated kW
during each Program Event. Participants must notiff the Company of their Nominated kW via the Program
Application. Once the Program Season begins, the Participant must submit the nomination change request form
online (located at www.idahopower.com/flexpeak) via email by Thursday at 10:00 a.m. MDT of the proceeding
week to notiff of any changes in Nominated kW. The Nominated kW may be raised or lowered each week
without restriction any time before the third manda+ery.11jlimum Program Event is called. After the third Program
Event is called, the Nominated kW may still be raised or lorered, 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 Fixed Capacity Payment, a_nV@igble Energy
Payment, and any applicable Nominated kW lncentive Adjustment. Both the Fixed Capaci$ and Variable Energy
Payments will be paid by check or bill credit no more than 3045 days after the Program Season concludes on
Aueust-SCptembCll5h.
When a Program Event is called and a Participant exceeds the Nominated kW. the Fixed Capaci$
Payment will be capped at 20 percent above original Nominated kW.
Fixed Caoacitv Pavment Rate*
(*to be prorated for partialweeks)
Variable Enerov Pavment Rate*
(*does not aoplv to first threefour Prooram Events)
$3.25 per Weekly Effective kW Reduction $0.1€28 per kWt
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.
(N)
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lssued by IDAHO POWER COMPANY
By Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
OREGON
lssued:
Effective with Service
Rendered on and after:
I Rdvice No._{€-4521-12
TDAHO PO\ /ER COMPANY F|R+SECONq_REVISED SHEET NO. 76-s
CANCELS
P.U.C. ORE. NO. E.27 ORICIAIALFIRST SHEET NO.7&5
SCHEDULE 76
FLEX PEAK
PROGRAM
(oPTroNAL)
(Continued)
INCENTIVE STRUCTURE (Continued)
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 Pregram Events; the Nerninated
in{enral-:
---Jhe 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 initially, but are automatically re-enrolled each year
thereafter. Participants wil! be notified prior to each Program Season of the automatic re-enrollment. This
Program Application must include the Facility Site(s) they wish to enroll and the initial Nominated kW for each
Facility Site. lf a Participant requests the Aggregated Option they must speciff this on the Program Application.
A Participant may terminate their participation in the Program at any time during or before the
Program Season by notiffing the Gompany in writing.
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 untilthe following calendar year.
SPECIAL CONDITIONS
The provisions of this Program do not apply for any time period that the Company requests a load
reduction during a system emergency in accordance with NERC standards. ldaho Power's Rule J. -or any [e-mail]
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.
(eq)
(cD)
(€)
1
2.
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G)
lssued by IDAHO POWER COMPANY
By Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
OREGON
lssued:
Effective with Service
Rendered on and after:
I nOvice No._-{€-1521-12 ebruary 15.2022
BEFORE THE
PUBLIC UTILITIES GOMMISSION OF OREGON
CASE NO. ADVl3ss/ADVICE NO. 21-12
IDAHO POWER COMPANY
REQUEST NO. 17
ATTACHMENT 1
SEE ATTACHED SPREADSHEET
BEFORE THE
PUBLIC UTIL]TIES COMMISSION OF OREGON
CASE NO. ADV1355/ADVICE NO. 21-12
IDAHO POWER COMPANY
REQUEST NO.23
ATTACHMENT NO. 1
SEE ATTACHED SPREADSHEET
BEFORE THE
PUBLIC UTILITIES COMMISSION OF OREGON
CASE NO. ADVl3s5/ADVICE NO. 21.12
IDAHO POWER COMPANY
REQUEST NO. 29
ATTACHMENT NO. 1
SEE ATTACHED SPREADSHEET