20131002Motion.pdf

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JULIAA. HILTON
Corporate Counse!
ihi [e-mail]
October 2,2013
VIA HAND DELIVERY
Jean D. Jewell, Secretary
!daho Public Utilities Commission
472 West Washington Street
Boise, ldaho 83702
Re: Case No. IPC-E-13-14
Continuation of Demand Response Programs - ldaho Power Company's
Motion to Approve Settlement Agreement
Dear Ms. Jewell:
Enclosed forfiling in the above matterare an original and seven (7) copies of ldaho
Power Company's Motion to Approve Settlement Agreement.
Very truly yours,
Julia A. Hilton
JAH:evp
Enclosures
An IDACORP Company
1221 W. ldaho St. (83702)
P.O. Box 70
Boise, lD 83707
JULIA A. HILTON (lSB No. 7740)
LISA D. NORDSTROM (!SB No. 5733)
Idaho Power Company
1221West ldaho Street (83702\
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
ih i lton@idahopower. com
I nord strom @ ida hopowe r. com
Attorneys for ldaho Power Company
IN THE MATTER OF THE
CONTINUATION OF IDAHO POWER
COMPANY'S A/C COOL CREDIT,
IRRIGATION PEAK REWARDS, AND
FLEXPEAK DEMAND RESPONSE
PROGRAMS FOR 2014 AND BEYOND
t'
1a!-: i.-'i-r_. t- -
CASE NO. IPC-E-13-14
IDAHO POWER COMPANY'S
MOTION TO APPROVE
SETTLEMENT AGREEMENT
i::': a., a! i
BEFORE THE !DAHO PUBLIC UTILITIES COMMISSION
COMES NOW, ldaho Power Company ("ldaho Powe/' or "Company") and
hereby moves the ldaho Public Utilities Commission ("Commission") pursuant to RP 56,
256, and 274 to approve the enclosed Settlement Agreement on or before January 1,
2014. This Motion is based on the following:
1. ln Docket Nos. IPC-E-12-29 and IPC-E-13-04, ldaho Power filed for
changes to its A/C Cool Credit program, lrrigation Peak Rewards program, and
FlexPeak Management program (collectively "DR Programs"). These filings were
prompted by the Load and Resource Balance Analysis performed during the
development of ldaho Powe/s 2013 lntegrated Resource Plan which does not project
any peak-hour capacity deficits until 2016.
IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT - 1
2. ln Order No. 32776, the Commission approved a stipulation entered into
by parties to IPC-E-12-29, including ldaho lnigation Pumpers Association ("llPA"), the
ldaho Conservation league (.lCL"), Snake River Alliance ("SRA"1, and the ldaho Public
Utilities Commission Staff ("Commission"). That stipulation described terms for the
temporary suspension of the A/C Cool Credit Program and lrrigation Peak Rewards
Program (Phase l). lt also requested that the Commission schedule a prehearing
conference to set a schedule for workshops and a procedural schedule so that parties
and stakeholders could evaluate changes for ldaho Power's DR Programs for the 2014
program season and beyond (Phase ll).
3. ln Order No. 32805, the Commission approved temporary changes to the
FlexPeak Management program and directed that public workshops address how to
continue the FlexPeak program in the future.
4. ln Order No. 32823, the Commission opened a new docket in this case
and set an informal prehearing conference to further evaluate Idaho Power's DR
Programs for the 2014 program season and beyond. ln keeping with its previous
orders, the Commission ordered that llPA, lCL, and SRA were designated as
intervening parties in this case. Petitions to intervene in this proceeding were filed by
the lndustrial Customers of ldaho Power ('lclP') and EnerNOC, lnc. ("EnerNOC"). The
Commission granted those petitions in Order No. 32828.
5. Following the June 12, 2013, prehearing conference, the parties set a
schedule for four workshops, which were held on July 10, July 23, August 7, and August
19. During the August 19,2013, workshop the parties agreed to an additional workshop
on August 27, 2013, which included settlement discussions that occurred pursuant to
IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT - 2
RP 272. The testimony of Tami White describes the workshop process in greater detail,
a copy of which is enclosed as Attachment No. 1.
6. Based upon these workshops held on July 10, July 23, August 7, August
19, and August 27 and settlement discussions that occurred pursuant to RP 272 on
August 27,2013, several parties, including Idaho Power, Gommission Staff, llPA, lCL,
SRA, EnerNOC, and non-party Mike Seamanl l"Signing Parties") agreed to resolve and
settle issues related to the reinstatement of ldaho Power's DR Programs for 2014 and
beyond. A copy of the signed Settlement Agreement evidencing the settlement is
enclosed as Attachment No. 2. The Signing Parties believe the settlement is in the
public interest and recommend that the Commission approve the Settlement Agreement
and all of its terms and conditions without material change or condition pursuant to RP
274.
5. Program modifications identified in the Settlement Agreement are
reflected in clean and legislative formats for Tariff Schedule 23 (lrrigation Peak Rewards
Program) and Tariff Schedule 81 (Residential Air Conditioner Cycling Program), both of
which are enclosed as Attachment No. 3. The Signing Parties recommend the
Commission issue its order approving these tariffs no later than January 1,2014.
NOW, THEREFORE, the Signing Parties respectfully request that the
Commission issue an order in Case No. IPC-E-13-14:
1. Granting the Motion to accept Attachment No. 2, the Settlement
Agreement, in its entirety, without material change or condition;
' Mike Seaman authorized the Company to use the electronic signature format of "/S/ Mike
Seaman."
IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT - 3
2. Acknowledging that the Company will be able to recover othenrise
prudent expenditures made under this Settlement Agreement, even though such
expenditures may not be cost-effective by traditional measures in the short or long-term;
and
3. Authorizing revised tariff schedules with an effective date of
January 1,2014.
Respectfully submitted this 2nd day of Octobe r 2013.
Attorney for ldaho Power Company
IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT.4
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 2nd day of October 2013 I served a true and
correct copy of the within and foregoing IDAHO POWER COMPANY'S MOTION TO
APPROVE SETTLEMENT AGREEMENT, upon the following named parties by the
method indicated below, and addressed to the following:
Commission Staff
Karl Klein
Deputy Attomey General
ldaho Public Utilities Commission
47 2 W est Wash ington (83702 )
P.O. Box 83720
Boise, ldaho 83720-007 4
Idaho lrrigation Pumpers Association, lnc.
Eric L. Olsen
RACINE, OLSON, NYE, BUDGE &
BAILEY, CHARTERED
201 East Center
P.O. Box 1391
Pocatello, ldaho 83204-1391
Anthony Yankel
29814 Lake Road
Bay Village, Ohio 44140
ldaho Conservation League
Benjamin J. Otto
ldaho Conservation League
710 North Sixth Street
Boise, ldaho 83702
Snake River Alliance
Ken Miller, CIean Energy Program Director
Snake River Alliance
P.O. Box 1731
Boise, Idaho 83701
lndustrial Gustomers of Idaho Power
Peter J. Richardson
RICHARDSON ADAMS, PLLC
515 North 27th Street (83702)
P.O. Box 7218
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IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT - 5
Dr. Don Reading
6070 Hill Road
Boise, ldaho 83703
EnerNOC, lnc.
Teresa A. Hill
K&L GATES, LLP
222 Columbia Street, Suite 1400
Portland, Oregon 97201
Melanie Gillette, Director Regulatory Affairs
EnerNOC, lnc.
115 Hazelmere Drive
Folsom, California 95630
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IDAHO POWER COMPANY'S MOTION TO APPROVE SETTLEMENT AGREEMENT - 6
BEFORE THE
IDAHO PUBLIC UTILITIES GOMMISSION
GASE NO. IPC-E-13-14
IDAHO POWER COMPANY
ATTACHMENT 1
BEEORE THE IDAHO PUBLIC UTILITIES COMMTSSION
IN THE MATTER OE THE
CONTINUATION OF IDAHO POV{ER
COMPANY' S A/C COOL CREDIT,
]RRIGATION PEAK REV{ARDS, AND
ELEXPEAK DEMAND RESPONSE
PROGRAMS FOR 2014 AND BEYOND
CASE NO.r Pc-E-13- 1 4
IDAHO POT'IER COMPANY
TESTIMONY IN SUPPORT OF SETTLEMENT AGREEMENT
OE
TAMI WHITE
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o.
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is 7227 West
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Idaho Power.
Please state your name and busj-ness address.
My name is Tami White and my business address
Idaho Street, Boise, Idaho 83702.
By whom are you employed and in what
I am employed by fdaho Power Company
capacity?
( " Idaho
DesignPower" or "Company") as the Senior Manager of Rate
in the Regulatory Affairs Department.
A.
Please describe your educational- background.
I earned a Bachelor of Business Administration
degree in Accounting from California State University,
Stanisl-aus. I have attended various electri-c utitity
courses, includj-ng "Electric Util-ity System Operation," a
course offered through Professional Training Systems, Tnc.,
and "Overview of System Operations" presented by the
Western Electricity Coordinating Council-.
o
Please describe your work experience with
A.I began my emplolrment with Idaho Power in 7999
as a Financial Analyst in the Company's DeJ-ivery Fj-nance
Support area where I provided accounting and financial
support servlces to the Delivery Business Unit. In 2005, T
was promoted to Finance Team Leader where I was responsible
for leading a group of Fj-nancial Analysts, Accountants, and
Accounting Specialists in providing accounting and
financial- support services to the Operations Business Unit.
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I I was responsible for all aspects of the monthly accounting
2 closing process for the Operations Business Unit and for
3 the monthly billing and settlements processes for
4 transmission sales and purchases, wholesale energy
5 transactions, Public Utility Regulatory Policies Act of
6 7978 (PURPA) transactions, large special contracts, and
1 )oint use transact j-ons. V0hi1e working in Operat j-ons
8 Fi-nance Support, I was involved in the development of the
9 Company's Eederal Energy Regulatory Commission (*FERC")
10 Open Access Transmission Tariff (*OATT") formula rate for
11 transmission services.
72 In October of 201,0, after 11 years in fi-nance, I
13 accepted a position as Manager of FERC and Regional Affaj-rs
14 in the Regulatory Affairs department. In this position I
15 was responsible for managing regulatory activities such as
L6 the preparation and filing of Idaho Power's OATT rates for
71 transmission service, supervising participation and
18 settlement negotiations of Bonnevill-e Power Administration
19 rate cases, and creating analyses that form the basis for
20 Idaho Power's EERC regulatory strategy.
2t In January of 2012, T was promoted to Senior Manager
22 of Rate Design. As Senior Manager of Rate Design, I
23 oversee the Company's rate design activities such as
24 regulatory ratemaking and compliance filings, tariff
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administration, and the development of various pricing
strategies and policies.
o.
proceeding?
What is the purpose of your testimony in this
A.The purpose of my testimony is to describe the
public workshop process undertaken in the above-captioned
matter and the agreement ("Settlement Agreement") that was
signed by Idaho Power, the Staff of the Idaho Pub1ic
Utilities Commisslon ("Staff"), Idaho Irri-gation Pumpers
Association, Inc., the Idaho Conservation League, the Snake
River Al-l-i-ance, EnerNOC, Inc., and Mike Seaman,
(coll-ectively referred to as the "Signing Parties") that
addresses and settles certain aspects of Idaho Power's
demand response programs. My testimony will provide the
Idaho Public Utilities Commission ("Commission") with an
overview of the workshops and the i-ssues discussed,
express Idaho Power's support for the Settlement Agreement,
and recommend that the Commi-ssion adopt the Settlement
Agreement without material- change or condition.
Overview
O. What prompted the public workshop proceedj-ngs?
A. In December of 20L2, Idaho Power filed a
request in Docket No. IPC-E-12-29 with the Commission for
authority to temporarily suspend two of its three demand
response ("DR") programs (A/C Cool Credit and Irrigation
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Peak Rewards). The request for suspension was prompted by
the lack of near-term peak-hour deficits identified in the
Peak Load and Resource Bal-ance analysis prepared for the
2013 Integrated Resource Plan ("fRP") and Idaho Power's
desi-re to take prompt and prudent steps to avoid some of
the expenses associated with the programs in years where
the Peak Load and Resource Bal-ance analysis does not show a
need. During the suspension, the Company was able to serve
l-oads with existing resources and work with stakeholders
through a coll-aborative workshop process to evaluate and
identify the best long-term solution for conti-nuatlon of
these programs.
In February of 20L3, the Company, Staff, and
intervenors filed a proposed stipulation that was approved
by the Commissj-on on April 2, 2073, in Order No. 32716,
temporarily suspending the A/C Cool- Credit and Irrigation
Peak Rewards DR programs for 2013. In this order, the
Commission opened a new docket (IPC-E-13-14) for the
purpose of evaluating the A/C Cool- Credit and Irrigation
Peak Rewards programs for 2074 and beyond and directed
Staff counsel- to convene an informal conference so the
parties could propose a schedule for the processing of this
case. Order No. 32776 at 8.
In a related filing in March of 2013, Idaho Power
filed a petition with the Commission in Case No. IPC-E-13-
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04 requesting approval- for changes to its third DR program,
Fl-exPeak Management, in an effort to reduce the cost of
this program tn 2013 because the Peak Load and Resource
Balance analysis indicated that the need for DR programs
had changed. This Petition was approved by the Commission
on May 9, 20L3, in Order No. 32805.
In May of 2073, the Public Utility Commj-ssion of
Oregon opened Docket No. UM 1653 to facilitate
participation by Oregon Staff and interested Oregon partl-es
in the Idaho workshop process.
On June 4, 2013, the Commission issued Order No.
32823 initiating a new proceeding in Case No. IPC-E-13-14
to examine the continuati-on of all three of Idaho Power's
demand response programs (A/C Cool Credit, Irrigatj-on Peak
Rewards, and EIexPeak Management, collectively "DR
Programs") and schedu1ing an informal prehearing conference
to al1ow the parties, the parties in Oregon's UM 1653, and
other interested persons, to schedul-e public workshops
regarding the continuation and/or modification of all three
of fdaho Power's DR Programs. Order No. 32823 at 2.
The prehearing conference was held on June 72, 2073,
and a schedule for the public workshops was established.
o.
process.
Please briefly describe the public workshop
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A.A series of fj-ve public workshops were held at
Idaho Power's corporate offices on July 10, JuLy 23, August
'7, August 19, and August 27, 20!3. The final workshop on
August 27th included settlement discussions. These
workshops included group discussions and presentations by
Company personnel, Staff, workshop participants, and
industry experts. Each of the workshops was facilitated by
a third-party, professional facllitator, Dune Ives, Ph.D.
of Milepost Consulting.
O. Who participated in the workshops?
A.In addition to Idaho Power personnel, nearly
50 individual-s representing 20 different organizations
attended one or more workshops, received meeting material-s
and summaries, and were considered to be workshop
participants ("ParticJ-pants"). A 11st of Participants is
included as Exhibit No. 1 to my testimony.
o.Were the Participants able to align on the
is sues ?
A.For the most part yes; however, it j-s
important to note that when I state that Participants
aligned, concluded, agreed, or reached consensus on a
particular issue, it does not indicate that every
individual agreed, however, it is meant to indicate that as
a group, Participants were able to reach consensus.
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o.Please provide a summary of the first workshop
content and outcomes.
A.The first workshop was designed to be
foundational- and educational in nature and included
presentations from Idaho Power personnel and industry
experts. Presenters and Participants discussed the results
of the 2073 IRP Peak Load and Resource analysis that shows
no near-term peak-hour capacity deficits until 2016, how
cost-effectiveness for fdaho Power's DR Programs is
calculated, l-essons learned from the history of DR Programs
at Idaho Power, operational considerations for DR Programs,
and how other utilities around the country utilize DR. In
this workshop, Participants also discussed hiqh Level
objectives for the workshop process and the parameters that
would provide the "side-boards" that Participants would
work within.
O.Please provide a summary of the second
workshop content and outcomes.
A.In the second workshop, Participants continued
to learn about how other DR programs across the country are
designed and operated, had discussions about how public
service commissions in other states regulate DR, and heard
a presentation about Rocky Mountaln Power's Irrigation DR
Program in Idaho and its Residential Air Conditioning DR
Program in Utah.
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In this second workshop, Participants al-so began to
discuss other potential uses for demand response beyond the
typical capacity resource at Idaho Power and aligned on the
high level objectives and parameters discussed in the first
workshop.
Participants 1n the second workshop concl-uded that
potential purposes for DR at Idaho Power j-ncluded delaying
new peaking capacity, avoi-ding line losses, providj-ng non-
spinning reserves, providing reliability and flexibility,
and providing load following. Of these potential purposes,
al-l- of the above except for load following were identified
as the primary potential purposes of DR whil-e load
followlng was identified as important to explore.
A1so, during the second workshop, two small
workgroups were convened to discuss and evaluate the use of
DR to provide non-spinning reserves and using DR to provide
load following.
Participants al-so came to two conclusions in the
second workshop: 1) continuity of program delivery is key
and 2) to achieve short-term DR, we need to take a long-
term DR perspective.
o.Please provide a summary of the third workshop
content and outcomes.
A. fn the third workshop, the smal1 workgroups
reported back to the larger group on the potential of using
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Idaho Power Company
1 DR for non-spinning reserves and/or l-oad following.
2 Participants revisited the cost-effectiveness discussion
3 and began the discussion on how to value DR. During the
4 third workshop, a small- workgroup was convened to eval-uate
5 and present a recommended value assessment for DR back to
6 the fu1l group at the next workshop.
7 Q. Please provide a summary of the fourth
8 workshop content and outcomes.
9 A. In the fourth workshop, the small workgroup
10 reported back to the larger group on a recommended value
11 assessment for DR at Idaho Power. Participants discussed
72 and began to align on how the value of DR at Idaho Power
13 shoul-d be determined.
74 Participants also rej-terated that the Company
15 should: leverage the resources it has (equipment and
16 program participants); include DR Programs for all customer
L7 classes; keep costs as low as possible; and, as Idaho
18 Power's IRP changes, re-evaluate the value calculation.
19 Keeping the val-ue assessment and the goal of
20 allowing program participants to continue to participate in
2l mind, three smal-I workgroups based on customer classes were
22 convened to evaluate and report back to the group on
23 potential program design suggestions. The non-spinni-ng
24 reserves and load fol-lowing workgroups were assigned to
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Idaho Power Company
1 create a white paper on issues or findings for the group by
2 the next workshop.
3 Q. Please provide a summary of the fifth workshop
4 content and outcomes.
5 A. In the fifth and final workshop, Participants
6 reached alignment on the value of DR at Idaho Power, heard
7 the small workgroups report back on potential- program
8 designs for each customer segment, and got a progress
9 update on the status of the reserves and load following
10 white papers. Program design ideas were presented with
11 much of the discussion focusing on program changes.
12 Vforkshop five afso included settlement discussions.
13 Support for Settlenent Agrreenent
74 O. Were the Signing Parties able to reach an
15 acceptabJ-e compromise refl-ected in a settlement agreement?
16 A. Yes. Signing Parti-es drafted, reviewed, and
L7 signed the Settlement Agreement that is provided as
18 Attachment No. 2 to Idaho Power's Motion to Approve
19 Settl-ement Agreement filed in this case.
20 O. Have al-l intervening parties 1n this case
2L joined in the Settl-ement Agreement?
22 A. No. The Industrial- Customers of Idaho Power
23 did not sign the Settlement Agreement.
24 O. Did Idaho Power sign the Settlement Agreement?
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A. Yes. The Company belleves that the
Agreement is a faj-r and reasonable resol-ution of
provides a reasonable approach for continuing DR
Settlement
issues and
Programs.
Agreement
the public
o.Do you believe that this Settlement
and its acceptance by the Commission would be in
interest ?
A.Yes I do. The Settlement Agreement and its
acceptance by the Commission will allow for the continued
operation of Idaho Power's demand response programs in a
manner that is cost-effective and operationally beneficial
to the electric system, and within the parameters that the
Company and Participants agreed upon.
o.Pl-ease summarize the terms of the agreement
reached by Signing Part j-es.
A.Signing Parties came to agreement on six high-
level demand response concepts that should guide Idaho
Power in the implementation of its DR Programs. These
high-Ievel concepts are listed in Section 4 (a) of the
Settlement Agreement. Signing Parties agreed on the value
as set forth in Section 6 of the Settlement Agreement.
Signing Parties also came to agreement on the deslgn
of the DR Programs as described in Sections 7 for the A/C
Cool Credit program, Section 8 for the Irrigation Peak
Rewards program, and Section 9 for the El-exPeak Management
program of the Settlement Agreement.
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Idaho Power Company
1- Recomendation for Approval
2 Q. Why should the Commission approve the
3 Settlement Agreement?
4 A. The Settlement Agreement and its acceptance by
5 the Commission wil-l allow the Company to leverage the
6 investment in existing DR infrastructure to continue the
7 operation of a cost-effectj-ve resource. The Settlement
8 Agreement will al-so maintain participation j-n the DR
9 Programs for a time in the future when they are truly
10 needed while minimizlng ongoing costs to Idaho Power's
11 customers. The additional program modifj-cations will make
12 the programs more flexible, reliable, and useful because of
13 the ability to respond with shorter notice to program
74 participants. Ultimately, keeping the DR Programs viable
15 will help Idaho Power to provide its customers reliable
16 service in times of extreme weather and water conditions.
t1 O. How does this benefit all Idaho Power
18 customers?
1,9 A. If approved, the Settlement Agreement wil-1
20 maintain existing DR Programs, equipment, and participation
27 by providing an opportunity for all current program
22 participants to continue to participate if they choose.
23 Through this settlement, the Company will be able to
24 util-ize the investment that Idaho Power's customers have
25 made in the existing equipment in the field.
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The Settlement Agreement provi-des DR Programs that
are scalable and f]exible. As the need identified in
future IRPs changes, Idaho Power can more easily add DR
capacity, and will maintain a minimum capacity of DR on
Idaho Power's system.
The Settlement Agreement increases flexibility for
the Company's system by reducing the amount of advance
notification required for program participants and
implementing a fixed and variabl-e incentive design for two
of the three DR Programs. The Settlement Agreement al-so
provides for the lnclusion of three dispatch events
included in the fixed incentive structure that will ensure
that the programs are used and ensure program participant
engagement.
O. Do you have any concluding remarks regarding
the public workshop process or the Settlement Agreement?
A. Yes. fdaho Power values the thoughtful and
candid feedback provided by the Participants and
appreciates the efforts of stakeholders. The workshops
resulted in a Settlement Agreement that will all-ow the DR
Programs to continue while reducing costs for customers and
enhancing flexibiJ-ity for Idaho Power's system.
O. Does this concl-ude your testimony?
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Idaho Power Company
A.Yes, it does.
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STATE OF IDAHO
County of Ada
I, Tami
truthfully, and
following:
SUBSCRIBED
October, 20L3.
I am employed by Idaho Power Company as a Senior
Manager in the Regulatory Affairs Department and am
competent to be a witness in this proceeding.
I declare under penalty of perjury of the laws of
the state of Idaho that the foregoing pre-filed testj-mony
and exhibit are true and correct to the best of my
information and belief.
DATED thls 2"d day of October, 20L3.
Tami White
ATTESTATION OF TESTTMONY
SS.
Vf,hite, having been duly sworn to testify
based upon my personal knowledge, state the
AND SWORN to before me this 2"d day of
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Idaho Power Company
.1lA't 0.c7
rtaO
Jl;e tJq
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPG-E-13-14
IDAHO POWER COMPANY
WHITE, DI
TESTIMONY
EXHIBIT NO.1
Not including ldaho Power personnel, the following people attended the workshops:
Name Affiliation
Derek Garret Dominion Energy Solution
Lucie Jackson Enernoc
Teresa Hil!Enemoc
Melanie Gillette Enernoc
Chris Ashley Enernoc
Josh Bode Freeman, Sullivan & Co.
Michael Hennen Honeywell SGS
Amanda Richards Honeyrell SGS
Kevin Laukner Honeywe!! SGS
Bridget Holmquist Honeywel! SGS
Ben Otto ldaho Conservation League
Zack Waterman ldaho Sierra Club
Elliot Werk Idaho State Senate, District 17
Sid Erwin !daho lrrigation Pumpers Association
Lynn Tominaga ldaho lnigation Pumpers Association
Brenda Tominaga !daho lrrigation Pumpers Association
Tony Yankel ldaho I rrigation Pumpers Association
Eric Olsen ldaho I rrigation Pumpers Association
Mike Heckler ldaho Power Customer
Mike Seaman ldaho Power Customer
Peter Richardson lndustrial Customers of ldaho Power
Don Reading lndustrial Customers of ldaho Power
Donn English Idaho Public Utilities Commission
Nikki Karpavich ldaho Public Utilities Commission
Bryan Lanspery ldaho Public Utilities Commission
Karl Klein ldaho Public Utilities Commission
Exhibit No. 1
Case No. IPC-E-13-14
T. White, IPC
Page 1 of2
Stacey Donohue ldaho Public Utilities Commission
Beverly Barker Idaho Public Utilities Commission
Randy Lobb ldaho Public Utilities Commission
Johanna Bell ldaho Public Utilities Commission
Don Strickler J.R. Simplot Company
Don Sturtevant J.R. Simplot Company
Justin Wootan King Hill lrrigation
Stace Campbell McCain Foods
Roger Geddes Monsanto/Seminis
Wendy Gerlitz Northwest Energy Coalition
Matt Wiggens Office of Energy Resources
Scott Pugrud Office of Energy Resources
John Chatburn Office of Energy Resources
Juliet Johnson Public Utility Commission of Oregon
Brittany Andrus Public Utility Commission of Oregon
Stephanie Andrus Public Utility Commission of Oregon
Bob Jenks Oregon Citizens Utility Board
Kaylie Kleln Oregon Citizens Utility Board
Sommer Templet Oregon Citizens Utility Board
Ken Miller Snake River Alliance
Chad Burden THG Energy Solutions
Exhibit No. 1
Case No. IPC-E-13-14
T. \A/hite, IPC
Page2 of 2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC.E.13.14
IDAHO POWER COMPANY
AITACHMENT 2
DEMAND RESPONSE PROGRAMS
SETTLEMENT AGREEMENT
This settlement agreement ("Settlement Agreement" or "Agreement") is entered into by
and among the following participants to the demand response workshops: Idaho Power
Company ("Idaho Power" or "Company"), the Staff of the Idaho Public Utilities Commission
('Staff'), the Idaho Irrigation Pumpers Associatiory Inc. ("IIPA"), the Idaho Conservation
League ("ICL"), the Snake River Alliance ("SRA"), EnerNOC, Inc. ("EnerNOC"), and Mike
Seaman. These entities and individuals are collectively referred to as the "Parties," and
individually as a "Partyi' to the Agreement.
WHEREAT wheru in late 2012, the Load and Resource Balance Analysis performed
during the development of Idaho Power's 2013Integrated Resource Plan showed no peak-hour
capacity deficit until 2016, Idaho Power filed for changes to its A/C Cool Credit program,
Irrigation Peak Rewards program, and FlexPeak Management program (collectively "DR
Programs") in Docket Nos. IPC-E-12-29 and IPC-E-13-04;
WHEREAT following the temporary suspension of the A/C Cool Credit program and
Irrigation Peak Rewards program in 2013 and contract changes for the FlexPeak Management
program, the Parties attended a series of five workshops ("DR Workshops") for all interested
parties and stakeholders to discuss how the Company includes demand response ("DR") in its
Integrated Resource Plan ("IRP"), how it calculates cost-effectiveness of D& the purpose of D&
Idaho Power's DR Programs and design, and settlement options for Idaho Power's DR
Programs lr:.2014 and beyond;
SETILEMENT AGREEMENT
Page 1 of lL
WHEREAT these DR Workshops occurred in Case No. IPC-E-13-'1,4, were noticed in
Docket UM L653, and were attended by parties to both dockets, as well as members of the
public and other stakeholders;
WHEREAS, UM 1553 followed the workshop process in Case No. IPC-E-13-14 in an
effort to allow all interested Idaho and Oregon parties and stakeholders to collectively provide
input and agree upon Idaho Power's DR Program details; and
WHEREAS, throughout the course of the DR Workshops, the Parties reached agreement
on certain aspects of Idaho Power's DR Programs.
NOW THEREFORE, in consideration of the mutual promises set forth herein, the
sufficiency of which is hereby acknowledged, the Parties agree as follows:
Recitals. The above-stated recitals are incorporated and made a part of this
agreement to the same extent as if the recitals were set forth in full at this point.
Public Interest. This Agreement is a fair, just, and reasonable compromise of
contested issues and its acceptance by the Idaho Public Utilities Commission ("IPUC" or
"Commission") would be in the public interest. The Agreement and its acceptance by the
Commission will reasonably resolve the issues related to Idaho Power's DR Programs.
Therefore, the Parties recommend that the Commission approve the Agreement and all of its
terms and conditions without material change or condition pursuant to IPUC RP 274.
Terrn. This Agreement shall be in effect beginning on the date it is approved by
the Commission and shall apply to Idaho Power's DR Programs for 201,4 and beyond until a
change occurs in Idaho Power's system operations or cost-effectiveness of a DR Program that
would warrant reevaluation of the Agreemenfs terms. In such event Idaho Power will consult
SETTLEMENT AGREEMENT
Page 2 of 11
its Energy Efficiency Advisory Group ('EEAG") and then make an appropriate filing at the
Commission. Similarly, a party to this Agreement, may petition the Commission to open a
docket to reevaluate the terms of this Agreement if Idaho Power experiences a change in system
operations or the cost-effectiveness of a DR Program so warrants.
4.Concepts. The Parties and workshop participants agreed that the following
overarching demand response concepts should guide Idaho Power's implementation of its DR
Programs:
a. The Company must:
i. Use existing demand response resources when possible. This
includes using, to the extent possible, current demand response equipment owned or available
to Idaho Power and participating demand response customers, which currently represents
approximately 400 megawatts ("MW") of potential demand response capacity.
ii. Include demand response offerings for all three customer classes
(residentiaf commercial/industrial, and irrigation).
iii. Keep costs as low as possible.
lv.
V.
Reevaluate the value calculation as the IRP changes.
Take a long-term outlook. In order to have viable demand
response prograrns in the long term, the programs must continue in the short term.
vi. Calculate the avoided cost used for demand response by using the
avoided capacity cost of a 170 MW single cycle combustion turbine ("SCCT') multiplied by the
effective load carrying capacity ("ELCC"), measured over 20 years, plus the corresponding
deferred energy savings for 60 program hours.
SETTLEMENT AGREEMENT
Page 3 of 11
Strive for consistency in dispatch requirements across DR
Programs.
b. Uses for demand response beyond reducing peak loads may be: load
following, non-spinning operating reserves, improved reliability during emergency situations,
and flexibility to address delays in building new supply-side peaking resources. The workshop
participants broke into small groups and discussed the possibilities of load following and
reseryes. Based upon these workgroup findings, Idaho Power will investigate the feasibility of
using demand response as operating reserves and make a determination on feasibility by the
end of the 3'd quarter of 201,4. If Idaho Power determines that a pilot is feasible, it will create a
proposal and work with Staff and other interested stakeholders to develop a pilot program.
c. This Agreement applies only to Idaho Power's Demand Response
Programs, and the concepts are not applicable to any of the Company's other DSM Programs.
Resource Size. The minimum size of the deferred resource used for the value
calculation is 770 MW. It is appropriate for Idaho Power to incur and recover costs based on
deferring this resource.
5. Value. The annual value of demand response is equal to the levelized annual
cost of the minimum size deferred resource, measured over a period of 20 years, plus the
corresponding deferred energy savings for 60 program hours. As of the date of this Agreemenf
the calculation leads to an annual value of $15.7 million dollars for the entire DR Program
portfolio. The demand response value calculation shall include this value even in years when
the IRP shows no peak-hour capacity deficit. The annual value calculation will be updated with
SETTLEMENT AGREEMENT
Page 4 of 11
vll.
each IRP based on changes that include, but are not limited to need, capital cosf or financial
assumptions.
7. A/C Cool Credit Progam. Idaho Power will implement the A/C Cool Credit
program in a manner consistent with the tariff Schedule 81. A true and correct copy of the tariff
is attached to this Agreement as Attachment L and is incorporated herein as if set forth in full at
this point.
a. Participants. Participants are residential customers who are presently
enrolled in the program and have a load control device installed. All paging devices installed at
current participants' residences will be replaced with AMl-compatible devices, with the goal of
completing replacement in time for the 2014 program season. Idaho Power will not actively
promote the A/C Cool Credit program to solicit new participants through marketing tactics, but
will accept new participants in this program who request to participate, regardless of whether
they were previously participants in the program. In order to use existing equipment Idaho
Power will contact and attempt to recruit customers who move into a home that already has a
Ioad control device installed. If a customer enrolls in the A/C Cool Credit program at a
residence that has a paging device, the load control device will be replaced with an AMI-
compatible device. Idaho Power will also attempt to recruit participants who change residences
to a location that does not have a load control device. An A/C Cool Credit program load control
device will remain in place unless a customer requests the load control device be removed.
b. Program Details. The A/C Cool Credit program will be available from
June 15 through August 15, Monday through Friday, excluding holidays. Each dispatch event
will last no longer than four hours for each participant. Dispatch events will not occur more
SETTLEMENT AGREEMENT
Page 5 of 11
than L5 hours per week or 50 hours per season. In the event of a system emergency, demand
response capacity from the A/C Cool Credit program will be available for immediate dispatch.
Idaho Power will conduct a minimum of three dispatch events per season. No advanced notice
to participants is required prior to executing each dispatch event. Participants, with advance
notice, may opt out of two events per season.
c. Incentive. Participants will receive a fixed incentive of $15 for the season,
which will be issued as a credit on one or more of the participanfs monthly bills for the
program months.
d. Program Size. If participation in the A/C Cool Credit Program changes,
Parties to this Agreement may file an application to modify the program as set forth in Section
3.
8. Irrigation Peak Rewards Program. Idaho Power will implement the Irrigation
Peak Rewards program in a manner consistent with the tariff Schedule 23. A true and correct
copy of the tariff is attached to this Agreement as Attachment 2 and is incorporated herein as if
set forth in full at this point.
a. Participants. Participation is limited to past Irrigation Peak Rewards
service locations where an active, working load control device exists as described in more detail
in Attachment 2. The Company will not actively market the Irrigation Peak Rewards program
as described in more detail in Attachment 2.
b. Program Details. The Irrigation Peak Rewards program will be available
from June 15 through August 15, Monday through Saturday, from 1:00 p.m.-9:00 p.m.,
excluding holidays. Each dispatch event will last no longer than four hours for each
SETTLEMENT AGREEMENT
Page 6 of 11
participant. Dispatch events will not occur more than fifteen (L5) hours per week or sixty (50)
hours per season. In the event of a system emergency, demand response capacity from the
Irrigation Peak Rewards program will be available for immediate dispatch. Idaho Power will
conduct a minimum of three dispatch events per season. Participants with Interruption Option
3 will be given at least four hours advanced notification. There will be no notification required
for participants with Interruption Options L and 2. Participants may opt out of an event. An
opt-out fee of $5.00 per kilowatt ('kW') per event will apply for the first three events and $1.00
per kW per event for subsequent events. The opt-out fee will not exceed the total bill credit for
the program season.
c. Incentive. Participants will receive a fixed incentive in the form of a
demand and energy component which is approximately $15 per kW per season, as set forth in
more detail in Attachment 2. The fixed incentive shall include the above-mentioned three
minimum dispatch events. If Idaho Power conducts dispatch events in the Irrigation Peak
Rewards program in addition to the three minimum dispatch events, Participants will receive a
variable incentive of $0.148 (or $0.199 for the 9:00 p.m. option) per kWh as set forth in more
detail in Attachment 2, whiclu with the realization rate included, results in a cost to Idaho
Power of approximately $0.22 per kWh.
FlexPeak Management ProEam. Idaho Power will implement the Flex Peak
Management program using the following design parameters.
a. Participants. Idaho Power will not actively seek to expand the capacity of
the FlexPeak Program. Participants are industrial and large commercial customers.
SETTLEMENT AGREEMENT
PageT of\\
b. Program Details. The FlexPeak Management program will be available
from June L5 through August 15, Monday through Friday, from 2:00 p.m.-8:00 p.m., excluding
holidays. Each dispatch event will last up to four hours per participant within the available
program hours. Dispatch events will not occur more than 50 hours per season. In the event of a
system emergency, demand response capacity from the FlexPeak Management program will be
available. Idaho Power will conduct a minimum of three dispatch events per season. There will
be two hours advanced notice to participants.
lncentive. A fixed and variable incentive structure may be appropriate,
as long as the variable portion is low enough that it does not prevent the program from being
dispatched. If a variable and fixed incentive structure is used, a minimum of three dispatch
events will be included in the fixed incentive. The variable incentive will be paid to participants
if Idaho Power conducts dispatch events in the FlexPeak Management program for more than
the three minimum dispatch events.
10. Confidentiality. As provided in RP 272, other than any testimony filed in
support of the approval of this Agreement, and except to the extent necessary for a Party to
explain before the IPUC its own statements and positions with respect to the Agreement all
statements made and positions taken in negotiations relating to this Agreement shall be
confidential and will not be admissible as evidence in this or any other proceeding.
ll. Commission Procedure. The obligations of the Parties under this Agreement are
subject to the Commission's approval of this Agreement in accordance with its terms and
conditions and upon such approval being upheld on appeal by a court of competent
iurisdiction. The Parties will submit this Settlement Agreement to the Commission and
SETTLEMENT AGREEMENT
Page 8 of 11
recommend approval in its entirety pursuant to RP 274. Parttes shall support this Agreement
before the Commission, and no Party shall appeal a Commission order approving the
Agreement or an issue resolved by the Agreement. If this Agreement is challenged by any
person not a party to the Agreement, the Parties to this Agreement reserve the right to file
testimony, cross-examine witnesses, and put on such case as they deem appropriate to respond
fully to the issues presented, including the right to raise issues that are incorporated in the
settlements embodied in this Agreement. Notwithstanding this reservation of rights, the Parties
to this Agreement agree that they will continue to support the adoption of the terms of this
Agreement.
If the Commission rejects any part or all of this Agreement, or imposes any additional
material conditions on approval of this Agreement, each Party reserves the right upon written
notice to the Commission and the other Parties to this proceeding, within 14 days of the date of
such action by the Commission, to withdraw from this Agreement. In such case, no Party shall
be bound or prejudiced by the terms of this Agreement, and each Party shall be entitled to seek
reconsideration of an IPUC Order, file testimony as it chooses, cross-examine witresses, and do
all other things necessary to put on such case as it deems appropriate.
No Party shall be deemed to have agreed that any method, theory, or principle of
regulation or cost recovery employed in arriving at this Agreement is appropriate for resolving
any issues in any other proceeding in the future.
12. Entire Agreement. This Agreement and its attachments constitute the entire
agreement between the Parties regarding the subject matter hereof. There are no oral or written
SETTLEMENT AGREEMENT
Page 9 of 11
understandings, representations, or commitments of any kind, express or implied, which are
not expressly described in this Agreement.
13. Severability. If, after Commission approval of this entire Agreement without
modification, any immaterial term or provision of this agreement that is found to be void,
prohibited, or unenforceable by local, state, or federal law shall be ineffective only to the extent
of such prohibition or unenforceability without invalidating the remaining provisions of this
Agreement. Upon a determination that any material term or provision is void, prohibited, or
unenforceable by locaf state, or federal law, the Parties shall negotiate in good faith to modify
this Agreement to maintain the original intent of the Parties without such material provision.
14. No Third-Par9 Beneficiaries. No right or obligation contained in this
Agreement shall inure to the benefit of any person or entity not a Party or successor or assign of
a Party.
L5.Counterparts. This Agreement may be executed in counterparts and each signed
counterpart shall constifute an original document.
[signature page follows]
SETTLEMENT AGREEMENT
Page 10 of 11
DATED this
-day
of September 2013.
ldaho Power Company ldaho Public
Staff
Utilities Gommission
By
Customer Relations & Energy Efficiency
Manager
ldaho lrrigation Pumpers Association,
lnc.
Karl Klein
Deputy Attomey General
ldaho Conservation League
By By
Sid Erwin
Vice President of llPA
Benjamin J. Otto
Attorney for ldaho Conservation
League
EnerNOC, lnc.Snake River Alliance
By By
Ken Miller
Clean Energy Program Director
Melanie Gillette
Director, Regulatory Affairs
By
Mike Seaman
ldaho Power Customer
SETTLEMENT AGREEMENT
Page 11 of 11
DATED tr,is 46y of Septernbe t'2013.
ldaho Power Company
By
Theresa Drake
Customer Relations & Energy Efficiency
Manager
ldaho lrrigation Pumpers Association,
lnc.
ldaho Public Utilities Commission
Staff
ldaho Conservation League
By
Ken Miller
Clean Energy Program Director
By
Benjamin J. Otto
Attorney for ldaho Conservation
League
EnerNOC, lnc.
Melanie Gillette
Director, Regulatory Affairs
Sid Erwin
Vice President of llPA
Snake River Alliance
By By
By
Mike Seaman
ldaho Power Customer
SE'TILI]M ENT AGREEMENT
Page 11 of 11
Deputy Attorney General
Oct OZ 13 O4:4Oa
DATED this
-day
of September 2013.
Idaho Power Company
Btt
Theresa Drake
Customer Relations & Energy Efficiency
Manager
ldaho lrrigation Pumpers Association,
lnc.
Karl Klein
Deputy Attorney General
ldaho Gonseruation League
ldaho Public
Staff
p.1
Utilities Commission
By
Snake River Alliance
Ken Miller
Clean Energy Program Director
By.
Mike Seaman
ldaho Power Customer
By
Benjamin J. Otto
Attomey for ldaho Conservation
League
EnerNOG, lnc.
By
Melanie Gillette
Director, Regulatory Affairs
By.
SETTLEMENT AGREEMENT
Page 11 of 11
Vice President of llPA
DArED ,*$lLrof september 2013.
ldaho Power Company
Theresa Drake
Customer Relations & Energy Efficiency
Manager
ldaho lrrigation Pumpers Association,
Inc.
ldaho
Staff
Public Utilities Commission
ByBy
Karl Klein
Deputy Attorney General
ldaho Conservation League
ByBy
By
Sid Erwin
Vice President of llPA
Snake River Alliance
Ken Miller
Clean Energy Program Director
Attorney for ldaho Conservation
League
EnerNOG, lnc.
Melanie Gillette
Director, Regulatory Affairs
By--
By
Mike Seaman
ldaho Power Customer
SETILEMENT AGREEMENT
Page 11 of 11
Benjamin J. Otto
-----____ _pATED this
-day
of September 2013.
ldalrs_P_qwe r C__o-tn p a,q y
-Py_ - _
Theresa Drake
-Qustomer Relations & Enerqy EflSle1qy
I{snascr
Eqeg_lLr!g?_tiS_tr__Pq11pe rs Associa ti on,
lnc.
B-y. _
Sid Enrvin
VtSe_PreSldg11tof llPA
Slete-Elyerl!liaqcs
ldaho Public Utilities CoI0m!$jon
Staff
Kar]Kletn
DeLug}tqrey Senegl
L4qhg_c-q[9e4{eti9_E_Leagqe
By
_Qenjgrnin J. Otto
at!eqey__&L! aho _!_o1ry1vqfu1
_Le_agp-e
EnerNOC. lnc.
By
Melanie Gillette
D i rector, R eg u lato-!:y. Atf.A[g
', .'*a
ly-Ai** fu)Ze
Ken Miller
l-1
Cl ea n E_nggy. PrcS fe.n_Queslgr
Mrke_S*eaugn
tdA ho_ISWer CUElqrn_eI
Bv
SETTLEMENTAGREEMENT
Page 11 of 11
DATED this
-day
of September 2013.
ldaho Power Company Public Utilities Commission
Theresa Drake Karl Klein
Customer Relations & Energy Efficiency Deputy Attomey General
Manager
ldaho lrrigation Pumperc Association, ldaho Conservation League
lnc.
By
ldaho
Staff
By_
Sid Erwin
Mce President of llPA
Benjamin J. Otto
Attorney for ldaho Conservation
League
EnerNOC, !nc.Snake River Alliance
By sv fR, oo,^., , sC t r,++-
Melafiie Gillette
By.
Ken Miller
Clean Energy Program Director Director, Regulatory Affairs
Mike Seaman
ldaho Power Customer
SETTLEMENT AGREEMENT
Page 11 of 11
DATED this
-day
of September 2013.
ldaho Power Company ldaho Public Utilities Commission
Staff
By By
Theresa Drake Karl Klein
Customer Relations & Energy Efficiency Deputy Attomey General
Manager
ldaho lrrigation Pumpers Association, ldaho Gonservation League
lnc.
By
Sid Erwin Benjamin J. Otto
Vice President of llPA Attorney for ldaho Conservation
League
Snake River AIIiance EnerNOC, lnc.
By
By
By
Ken Miller
Clean Energy Program Director
Melanie Gillette
Director, Regulatory Affairs
By / s / Mi kp .so:men
Mike Seaman
ldaho Power Customer
SETTLEMENT AGREEMENT
Page 11 of 11
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPG-E-13-14
IDAHO POWER COMPANY
ATTACHMENT 3
CLEAN FORMAT
ldaho Power Company Sixth Revised Sheet No.23-1
Cancels
!.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-1
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
PURPOSE
The lrrigation Peak Rewards Program (the Program) is an optional, supplemental service that
permits participating agricultural irrigation Customers taking service under Schedule 24 to allow the
Company to turn off specific irrigation pumps with the use of one or more Load Control Devices. ln
exchange for allowing the Company to turn off specified irrigation pumps, participating Customers will
receive a financial incentive for load reductions during the calendar months of June, July, and August
for each metered service point (Metered Service Point) enrolled in the Program.
AVAILABILITY
Service under this schedule is available on an optional basis to Customers with a Metered
Service Point or Points receiving service under Schedule 24where the Metered Service Point serves a
water pumping or water delivery system used to irrigate agricultural crops or pasturage. The Program
is only available to Customers that have an existing dispatchable Load Control Device installed on their
equipment and existing participants under lnterruption Option 3. Customers enrolled in the Program
under the Timer Option in 2012 must either enroll in the Program under an lnterruption Option that uses
a dispatchable Load Control Device prior to the 2014 Program Season or no longer participate in the
Program.
The Company shall have the right to select and reject Program participants at its sole discretion
based on criteria the Company considers necessary to ensure the effective operation of the Program.
Selection criteria may include, but will not be limited to, Billing Demand, location, pump horsepower,
pumping system configuration, or electric system configuration. Past participation does not ensure
selection into the Program in future years. Participation may be limited based upon the availability of
Program equipment and funding.
Each eligible Customer who chooses to take service under this optional schedule is required to
enter into a Uniform 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 property to maintain one or
more Load Control Devices on the electrical panel servicing the irrigation equipment associated with
the Metered Service Points that are enrolled in this Program and to allow the Company or its
representative reasonable access to the Load Control Device(s). By entering into the Agreement, each
Customer also agrees to not increase for the sole purpose of participating in the Program the capacity,
horsepower (HP) or size of the irrigation system served by the Company.
PROGRAM DESCRIPTION
Service under this optional, supplementary Program permits the Company to turn off specified
irrigation pumps for a limited number of hours during the period of June 15 through August 15 (Program
Season). The Company will utilize dispatchable Load Control Devices to turn off specific irrigation
pumps during Load Control Events. ln limited applications, a select group of eligible Customers will be
permitted to manually interrupt electric service to participating irrigation pumps during Load Control
Events (See Interruption Option 3). ln exchange for allowing the Company to interrupt service to
specified irrigation pumps, participating Customers will receive a financial incentive for usage that
occurs during the calendar months of June, July, and August for each Metered Service Point enrolled in
the Program.
!DAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-2
Cancels
I.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-2
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
DEF!NlTIONS
Notification of Proqram Acceptance. An interested Customer must sign and return to the
Company an Agreement specifying the Metered Service Point(s) to be included in the Program. 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.
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.
Prooram Season. The Program Season is the period June 15 through August 15 of each year.
Prooram kW. The Program kW is the demand amount, as measured at the Customer's meter in
kilowatts (kW) during the Program Season, that is multiplied by the applicable incentive amount to
determine the Demand Credit under each lntenuption Option.
Nominated Demand. Nominated Demand is the amount of demand that participants under
lnterruption Option 3 must declare as available for dispatch during Load Control Events.
Proqram kWh. The Program kWh is the energy amount, as measured at the Customer's meter
in kilowatt-hours (kwh) during the Program Season, that is multiplied by the applicable incentive
amount to determine the Energy Credit under each lnterruption Option.
Variable Prooram kWh. The Variable Program kWh is the demand amount, as measured at the
Customer's meter in kilowatts (kW) multiplied by the hours of interruption for the Metered Service Point
during the Program Season. The Variable Program kWh is multiplied by the applicable variable
incentive payment to determine the Variable Energy Credit under each !nterruption Option.
Variable Program kWh = metered kW x hours of interruption during Program Season
Bill Credit. The Bill Credit is the sum of the Demand Credit and the Energy Credit applied to the
Customer's monthly bills for usage that occurs during the calendar months of June, July, and August of
each calendar year. This amount may be prorated for the number of days during the months of June,
July, and August that fall in the Customer's billing cycle to correspond with the Program Season. The
Bill Credit amount may be applied directly to participating Customers' bills or provided in the form of a
check.
Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly
Demand Credit is calculated by multiplying the Program kW by the demand-related incentive amount
for the 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, and August of
each year. This amount may be prorated for the number of days during the months of June, July, and
August that fall in the Customer's billing cycle to correspond with the Program Season.
Demand Credit = Program kW x demand-related incentive amount
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-3
Cancels
!.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-3
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
DEFIN ITIONS (Continued)
Enerov Credit. The Energy Credit is an energy-based financial incentive provided in the form of
a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Energy
Credit is calculated by multiplying the Program kWh by the energy-related incentive amount for the
lnterruption Option selected by the Customer. The Energy Credit will be included on the Customer's
monthly bills for usage that occurs during the calendar months of June, July, and August of each year.
This amount may be prorated for the number of days during the months of June, July, and August that
fall in the Customer's billing cycle to correspond with the Program Season.
Energy Credit = Program kWh x energy-related incentive amount
Variable Enerqv Credit. The Variable Energy Credit is an energy-based financial incentive
provided for the Metered Service Point enrolled in the Program. The Variable Energy Credit is
calculated by multiplying Variable Program kWh by the energy-related incentive amount for the
lnterruption Option selected by the Customer. The Variable Energy Credit is paid in the form of a check
no later than 45 days after the Program Season. This amount may be prorated for the number of days
during the months of June, July, and August that fall in the Customer's billing cycle to correspond with
the Program Season.
Variable Energy Credit = Variable Program kWh x variable energy-related incentive amount
INTERRUPTION OPTlONS
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 1:00 P.M. and 8:00 P.M. Mountain Daylight Time (MDT), excluding holidays (Standard
lnterruption). Customers may elect to participate until 9:00 P.M. MDT (Extended lnterruption) and will
receive a larger Variable Energy Credit. Service interruptions may last up to 4 hours per day and will
not exceed 15 hours per calendar week and 60 hours per Program Season. During each Program
Season the Company will conduct a minimum of three Load Control Events. Customers participating in
lnterruption Option 1 and Option 2 may not receive advance notification of a Load Control Event.
Notification will be sent to Customers under lnterruption Option 1 and Option 2 after the Load Control
Event begins. Customers participating in lnterruption Option 3 will receive advance notification at least
4 hours prior to the 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:
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-4
Cancels
].P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-4
SCHEDULE 23
IRRIGATTON PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
I NTERRUPTION OPTIONS (Continued)
Option 1. A dispatchable one-way communication 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 Option 1 will provide the
Company the ability to send a signal that will interrupt 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 Option 1, the Program kW will be based upon the monthly Billing Demand,
as measured in kW, for the associated Billing Period. The Program kWh under this option will
be based upon the monthly energy usage, as measured in kWh, for the associated Billing
Period.
Customers selecting Option 1 may opt-out of a Load Control Event up to five
times per season prior to or during a Load Control Event. Each time a customer chooses to opt-
out of one of the three minimum Load Control Events a fee of $5.00 per kW will be assessed
based upon the current Billing Period's kW. Each time a customer chooses to opt-out of a Load
Control Event after the three minimum Load Control Events a fee of $1.00 per kW will be
assessed based upon the current Billing Period's kW. The opt-out fee will not exceed the total
Bill Credit for the Program Season. Any opt-out fee will be applied at the end of the Program
Season.
Option 2. A dispatchable Load Control Device capable of two-way communication will be
connected to the electrical panel(s) servicing the irrigation pumps associated with the Metered
Service Points enrolled in this Program. The Load Control Device utilized under Option 2 will
provide the Company and the Customer remote control and monitoring of the associated
irrigation pumps. Under this option, the Company will use this technology to send a signal that
will interrupt or not allow the irrigation pumps to operate during dispatched Load Control Events.
This option requires that all pumps at the Metered Service Point be controlled.
Under Option 2, the Program kW will be based upon the monthly Billing Demand,
as measured in kW, for the associated Billing Period. The Program kWh under this option will
be based upon the monthly energy usage, as measured in kWh, for the associated Billing
Period.
Customers selecting Option 2 may opt-out of a Load Control Event up to five
times per season prior to or during a Load Control Event. Each time a customer chooses to opt-
out of one of the three minimum Load Control Events a fee of $5.00 per kW will be assessed
based upon the current Billing Period's kW. Each time a customer chooses to opt-out of a Load
Control Event after the three minimum Load Control Events a fee of $1.00 per kW will be
assessed based upon the current Billing Period's kW. The opt-out fee will not exceed the total
Bill Credit for the Program Season. Any opt-out fee will be applied at the end of the Program
Season.
!DAHO
lssued per Order No.
Effective - January 1, 2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-5
t.p.u.c. No. 2e. Tariff No. 101 Fifth Revised sheet 1f;;1:];
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
I NTERRUPTION OPTIONS (Continued)
Option 3. Metered Service Points with interval metering having more than one pump and at
least 1,000 cumulative HP are eligible for Option 3. Under Option 3, eligible Customers have
the flexibility to choose which irrigation pumps will be interrupted during each dispatched Load
Control Event. Customers electing this option must notify the Company of their Nominated
Demand prior to June 1 of each year.
Customers selecting Option 3 are required to provide no less than their
Nominated Demand during each Load Control Event. Each time a customer chooses to provide
less than their Nominated Demand during one of the three minimum Load Control Events, an
opt-out fee of $5.00 per kW will be assessed on the Nominated Demand not made available for
interruption. Each time a customer chooses to provide less than their Nominated Demand
during a Load Control Event, after the three minimum Load Control Events, an opt-out fee of
$1.00 per kW will be assessed on the Nominated Demand not made available for interruption.
The opt-out fee will not exceed the total Bill Credit for the Program Season. Any opt-out fee will
be applied at the end of the Program Season.
Under Option 3, the Program kW will be based upon the maximum measured
interval demand during the 24-hour period preceding 8:00 A.M. MDT the day of the
announcement of a Load Control Event, minus the average demand during an event, as
measured in kW over applicable load profile metering intervals. This applies to each Load
Control Event initiated during a Billing Period. 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 kWh. The Program kWh will
be calculated separately for each Billing Period by multiplying the monthly Program kW by the
ratio of the monthly energy usage to the Billing Demand for the associated Billing Period.
INCENTIVE STRUCTURE
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 45 days after the end of the Program
Season. The first three Load Control Events will not be subject to the Variable Energy Credit. The
variable payment will be based on the number of hours a participant's pump is interrupted during the
Program Season and their associated Program kW after the first three Load Control Events.
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-6
Cancels
|.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-6
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
I NCENTIVE STRUCTURE (Continued)
TERM OF AGREEMENT AND TERMINATION
The term of the Agreement, as it applies to each Metered Service Point accepted for
participation, shall commence on the date the Agreement is signed by both the Customer and the
Company and shall automatically renew on March 15 of each calendar year unless notice of
termination is given by either party to the other prior to the annual renewal date or unless otherwise
terminated as follows:
1. A Customer may terminate the participation of a Metered Service Point and avoid the
Termination Fee by notifying the Company or its representative before the Program Season.
2. A Customer who terminates the participation of a Metered Service Point anytime
between June 15 and August 15 of each calendar year shall pay the Company a Termination
Fee, which sum will be included on the Customer's monthly bill following termination of
participation. The Customer's Bill Credit shall be prorated for the number of days in that month
the Customer satisfactorily participated in the Program. Upon terminating participation of a
Metered Service Point under the provisions of item 2, the Customer may not re-enroll the
Metered Service Point into the Program until the following calendar year and the applicable
Termination Fee has been paid in full.
Termination Fees:
lnterruption Options 1 and 2: $500.00 per Metered Service Point terminated under item 2
3. lf there is evidence of alteration, tampering, or otherwise interfering with the Company's
ability to initiate a Load Control Event at a Metered Service Point, the Agreement as it applies to
that Metered Service Point will be automatically terminated. ln addition, the Customer will be
subject to each of the following:
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
lnterruption Option
Fixed lncentive Payment Variable lncentive Payment
lnterruption
Option
Demand Credit
($ per Proqram
xW)
Enerqv Credit
($ per Proqram
kwh)
Standard
lnterruption
Variable Enerov
Credit
($ oer Variable
Prooram kWh)
Extended
lnterruotion
Variable Enerov
Credit
($ per Variable
Prooram kWh)
1 $5.00 $0.0076 $0.148 $0.198
2 $5.00 $0.0076 $0.148 $0.198
3 $5.00 $0.0076 $0.148 $0.198
ldaho Power Company Sixth Revised Sheet No. 23-7
t.p.u.c. No. 29. Tariff No. 101 Fifth Revised sheet 1f;;1c;];
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
TERM OF AGREEMENT AND TERMINATION (Continued)
a. The Customer will be required to reimburse the Company for the cost of
replacement or repair of the Load Control Device(s), including labor and other related
costs.
b. An applicable Termination Fee, as provided under item 2, will be applied to the
Customer's monthly billfollowing the termination of participation.
c. The Company will reverse any and all Demand Credits and/or Energy Credits
applied to the Customer's monthly bill(s) for the Metered Service Point as a result of the
Customer's participation in the Program during the current year.
Note: A service disconnection for any reason does not terminate the Agreement.
SPECIAL CONDIT!ONS
The provisions of this schedule do not apply for any time period that the Company utilizes a
Load Control Device installed under this Program to interrupt the Customer's load for a system
emergency or any other time that a Customer's service is interrupted by events outside the control of
the Company. The provisions of this schedule will not affect the calculation or rate of the regular
Service, Energy or Demand Charges associated with a Customer's standard service schedule.
!DAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Sixth Revised Sheet No. 23-8
Cancels
|.P.U.C. No. 29. Tariff No. 101 Fifth Revised Sheet No. 23-8
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
Uniform lrriqation Peak Rewards Service
Application/As reement
THIS AGREEMENT Made this
between
day of
hereinafter called
Customer, whose billing address is
and IDAHO POWER COMPANY, a corporation with its principal office located al 1221 West 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 following person as the Customer's authorized contact:
Authorized Contact:
Phone:
Fax:
Cell Phone:
Email:
1.
2.
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.
The Customer understands that the information concerning the Metered Service Point(s) on the
Worksheet is based on the best information currently available to the Company. The Bill Credit
amounts are estimates based on the previous year's billing history for the Metered Service
Point(s) specified on the Worksheet. Customers without sufficient billing history will be provided
an estimated Bill Credit based on the stated cumulative horsepower at the Metered Service
Point. The Bill Credit estimates are provided for illustration purposes. The Customer agrees to
specify which Metered Service Point(s) listed on the Worksheet the Customer wishes to enroll in
the Program and the lnterruption Option selected for each specified Metered Service Point. For
Metered Service Points enrolled in lnterruption Option 3 the Customer must notify the Company
of Nominated Demand amounts by June 1 of each year.
IDAHO
lssued per Order No.
Effective - January 1, 2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifth Revised Sheet No.23-9
Cancels
|.P.U.C. No. 29. Tariff No. 101 Fourth Revised Sheet No. 23-9
5.
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
Uniform lrriqation Peak Rewards Service
Appl ication/Aq reement
(Continued)
From time to time during the term of this Agreement and with prior reasonable notice from the
Company, the Customer shall permit the Company or its representative to enter the Customer's
property on which the enrolled Metered Service Point(s) are located to permit the Company or
its representative to install, service, maintain and/or remove Load Control Device(s) on the
electrical panel that services the Customer's irrigation pumps. The Load Control Device(s) may
remain in place on the Customer's property upon termination of the Agreement unless the
Customer specifically req uests removal.
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 under
which a Load Control Event is scheduled for each Metered Service Point. The Customer also
understands and acknowledges that if a Metered Service Point provides electricity to more than
one irrigation pump, each pump will be scheduled for service interruption simultaneously,
excluding Metered Service Points participating in the Program under lnterruption Option 3.
For the Customer's satisfactory participation in the Program, the Company agrees to pay the
Customer the Demand Credit and/or Energy Credit corresponding to the lnterruption 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 of the prior year. The Bill Credit will be paid in the form of a credit on the
Customer's monthly bill or provided in the form of a check. The Demand Credit may be
prorated for the months of June, July, and August depending on the Customer's billing cycle.
Metered Service Points with interval metering, at least 1,000 cumulative HP and participating
under lnterruption Options, 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.
lf the Customer terminates this Agreement anytime between June 15 and August 15 of the
current calendar year while the Metered Service Point(s) are still connected for service the
Customer may not re-enroll that Metered Service Point into the Program until the following
calendar year and the applicable Termination Fee has been paid in full.
6.
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifth Revised Sheet No. 23-10
Cancels
l.P.U.C. No. 29. Tariff No. 101 Fourth Revised Sheet No. 23-10
7.
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
Uniform lrriqation Peak Rewards Service
Appl ication/Aq reement
(Continued)
!f there is evidence of alteration, tampering, or otherwise interfering with the Company's ability
to initiate a Load Control Event at a Metered Service Point(s), the Agreement as it applies to
that Metered Service Point will be automatically terminated. The Customer will also be required
to reimburse the Company for all costs of replacement or repair of the Load Control Device(s),
including labor and other related costs, pay the Company the applicable Termination Fee which
sum will be included on the Customer's monthly bill and the Company will reverse any Demand
Credits applied to the Customer's monthly bill(s) for the Metered Service Point as a result of the
Customer's participation in the Program during the current year.
The Company's Schedule 23, any revisions to that schedule and/or any successor schedule are
to be considered part of this Agreement.
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.
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.
ln any action at law 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, incurred on account of such action.
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.
8.
9.
10.
11.
12.
IDAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifth Revised Sheet No. 23-11
Cancels
].P.U.C. No. 29. Tariff No. 101 Fourth Revised Sheet No. 23-11
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
(oPTroNAL)
(Continued)
Uniform lrrioation Peak Rewards Service
Application/Aq reement
(Continued)
13. Under no circumstances shall the Company or any subsidiary, affiliates or parent Company be
held liable to the Customer or any other party for damages or for any loss, whether direct,
indirect, consequential, incidental, punitive or exemplary resulting from the Program or from the
Customer's participation in the Program. The Customer assumes all liability and agrees to
indemnify and hold harmless the Company and its subsidiaries, affiliates and parent company
for personal injury, including death, and for property damage caused by the Customer's decision
to participate in the Program and to reduce loads.
The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Load Control Device(s) and any and all implied warranties are disclaimed.
(Appropriate Signatures)
!DAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Second Revised Sheet No. 81-1
Cancels
I.P.U.C. No. 29. Tariff No. 101 First Revised Sheet No. 81-1
SCHEDULE 81
RESIDENTIAL AI R CONDIT!ONER
CYCLING PROGRAM
(oPTroNAL)
PURPOSE
The Residential Air Conditioner Cycling Program is an optional, supplemental service that
permits participating residential Customers an opportunity to voluntarily allow the Company to cycle
their central air conditioners with the use of a direct load control Device installed at their residence.
Customers will receive a monetary incentive for successfully participating in the Program during the Air
Conditioning Season.
DEFIN!TIONS
AC Cvclinq is the effect of the Company sending a signal to a Device installed at the Customer's
residence and instructing it to cycle the Central Air Conditioning compressor for a specified length of
time.
Air Conditionino Season is the period that commences on June 15 and continues through
August 15 of each calendar year.
Central Air 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
Customer's residence.
Cvclino Event is a period during which the Company sends a signal to the Device installed at
the Customer's residence, which instructs the Device to begin AC Cycling.
Device is a direct load control device installed at a Customer's residence that enables the
Company to conduct AC Cycling.
Notification refers to the Customer's indication of intent to initiate or terminate participation in the
Program by either contacting the Company's Customer Service Center, providing written notice or
submitting an electronic Application via the Company's website.
Opt Out is the term used to describe the two times each Air Conditioning Season in which the
Customer may choose to temporarily not participate in AC Cycling by providing advanced Notification to
the Company.
Prooram Operation Area describes the area in which the Program will be offered to Customers
and is comprised of the Company's service territory within the State of ldaho where the infrastructure
required to support AC Cycling has been installed and is operational.
IDAHO
lssued per Order No.
Effective - January 1, 201 4
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Third Revised Sheet No. 81-2
Cancels
l.P.U.C. No. 29. Tariff No. 101 Second Revised Sheet No. 81-2
SCHEDULE 81
RESlDENTlAL A!R COND!T!ONER
CYCLING PROGRAM
(oPTroNAL)
(Continued)
AVAILABILITY
Service under this schedule is available on an optional basis to Customers taking service under
Schedule 1 or Schedule 5 who have Central Air Conditioning located at their residences and live within
the Program Operation Area. 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 limited to, energy usage, residential location,
size of home, or other factors. Customers' Central Air Conditioning equipment must be fully functional
and comply with the National Electric Code (NEC) standards. Customers who are renting or leasing
their home must provide to the Company written proof of the express permission of the owner of the
CentralAir Conditioning system prior to acceptance into the program.
TERMS AND CONDITIONS
Upon acceptance into the Program, Customers will be subject to the following terms and
conditions:
1. 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 property to install a Device and, in certain cases, either 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 following its installation.
2. Customers added to the Program during the Air Conditioning Season must be effectively
participating in the Program prior to the 20th day of the month in order to receive an incentive payment
for that month.
3. A Customer may Opt Out of the Program two times during the Air Conditioning Season.
4. A Customer may discontinue participation in the Program without penalty by providing
Notification to the Company.
5. lf there is evidence of alteration, tampering, or otherwise 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 Customer's participation in the Program.
!DAHO
lssued per Order No.
Effective - January 1, 2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Second Revised Sheet No. 81-3
Cancels
!.P.U.C. No. 29. Tariff No. 101 First Revised Sheet Nos. 81-3
SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(oPTroNAL)
(Continued)
PROGRAM DESCRIPTION
1. At the Company's expense, the Company or its representative will install a Device at the
Customer's residence.
2. A financial incentive of $5.00 per month for each of the three months of June, July, and
August will be paid to each Customer who successfully participates in the Program. This incentive will
be paid in the form of a credit on the Customer's monthly bill for each month that the Customer
successfully participates in the Program, beginning with the July bill and ending with the September bill.
lncentive payments are limited to one controlled CentralAir Conditioning unit per metered service point.
Customers who have more than one Central Air Conditioning unit at a metered service point may
participate in the Program. A Device must be installed at each Central Air Conditioning unit. However,
no additional incentive will be paid.
3. The Company will send a signal to the Device to initiate a Cycling Event. A Cycling
Event may be up to four hours per day on any weekday during the Air Conditioning Season, excluding
holidays. A Cycling Event may occur over a continuous 4-hour period or may be segmented
throughout the day at the Company's discretion in order to optimize available resources. Cycling
Events may occur up to 15 hours each week and will not exceed a total of 60 hours per Air Conditioning
Season. During each Air Conditioning Season, the Company will conduct at least three Cycling Events.
Mass memory meters or end-use meters may be installed on some Customers' residences or Central
Air Conditioning units for program evaluation purposes. The residences or Central Air Conditioning
units selected for installation of the meter shall be at the Company's sole discretion.
SPECIAL CONDITIONS
The Company is not responsible for any consequential, incidental, punitive, exemplary or
indirect damage to the participating Customer or third parties that results from AC Cycling, from the
Customer's participation in the Program, or of Customer's efforts to reduce peak energy use while
participating in the Program.
The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Device and any and all implied warranties are disclaimed.
The Company shall have the right to select the AC Cycling schedule and the percentage of
Customers' Central Air Conditioning systems to cycle at any one time, up to 100o/o, at its sole
discretion.
The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer's load for a system emergency or any other time that a Customer's service is interrupted by
events outside the control of the Company. The provisions of this schedule will not affect the
calculation or rate of the regular Service or Energy Charges associated with a Customer's standard
service schedule.
!DAHO
lssued per Order No.
Effective - January 1,2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
LEGSLIATIVE FORMAT
ldaho Power Company Fifthsixth Revised Sheet No.23-1
r.p.u.c. No. 29. Tarifr No. 101 FeudhFifth Revised sheet 1f;;1:];
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
Serviee under this iee
ien_
PURPOSE
The lrrigation Peak Rewards Program (the Program) is an optional, supplemental service that
permits participating agricultural irrigation Customers taking service under Schedule 24 to allow the
Company to turn off specific irrigation pumps with the use of one or more Load Control Devices. ln
exchange for allowing the Company to turn off specified irrigation pumps, participating Customers will
receive a financial incentive for load reductions during the calendar months of June, July, and August
for each metered service point (Metered Service Point) enrolled in the Program.
AVA!LABILITY
Service under this schedule is available on an optional basis to Customers with a Metered
Service Point or Points receiving service under Schedule 24where the Metered Service Point serves a
water pumping or water delivery system used to irrigate agricultural crops or pasturage. The Proqram
is onlv available to Customers that have an existinq dispatchable Load Control Device installed on their
equipment and existinq participants under lnterruption Option 3. Customers enrolled in the Prooram
under the Timer Option in 2012 must either enroll in the Proqram under an lnterruption Option that uses
a dispatchable Load Control Device prior to the 2014 Prooram Season or no lonoer particioate in the
Proqram.
The Company shall have the right to select and reject Program participants at its sole discretion
based on criteria the Company considers necessary to ensure the effective operation of the Program.
Selection criteria may include, but will not be limited to, Billing Demand, location, pump horsepower,
pumping system configuration, or electric system configuration. Past participation does not ensure
selection into the Program in future years. Participation may be limited based upon the availability of
Program equipment and funding.
Each eligible Customer who chooses to take service under this optional schedule is required to
enter into a Uniform 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 property to insta#mai41lain
one or more Load Control Devices on the electrical panel servicing the irrigation equipment associated
with the Metered Service Points that are enrolled in this Program and to allow the Company or itsrepresentativereasonableaccesstotheLoadControlDevice(s)@.Byentering
into the Agreement, each Customer also agrees to not increase for the sole purpose of participating in
the Program the capacity, horsepower (HP) or size of the irrigation system served by the Company.
PROGRAM DESCRIPTION
Service under this optional, supplementary Program permits the Company to turn off specified
irrigation pumps for a limited number of hours during the period of June 15 through August 15 (Program
Season). The Company will utilize either<lispatchable €"E+im€Fbas€+Load Control Devices to turn off
specific irrigation pumps during lload eQontrol elvents. ln limited applications, a select group of
eligible Customers will be permitted to manually interrupt electric service to participating irrigation
IDAHO
lssued per Order No. 32776
Effective - Apnl&rugD( 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No.23-1
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-1pumpsduringlLoade9ontrole!vents(See@option3).Inexchangefor
allowing the Company to interrupt service to specified inigation pumps, participating Customers will
receive a financial incentive for usage that occurs during the calendar months of June, July, and August
for each Metered Service Point enrolled in the Program.
IDAHO
lssued per Order No. 32776
Effective - April&ruery 1, 20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-2
Cancels
LP.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-2
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
DEFINITIONS
Notification of Proqram Acceptance. An interested Customer must sign and return to the
Company an Agreement specifying the Metered Service Point(s) to be included in the Program. 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.
Load Control Device. Load Control Device refers to any technology, device, or system utilized
under the Program to enable the Company to initiate the [oad eQontrolelvent.
Load Control Event. Refers to an event under the Proqram where the Companv requests or
calls for interruption of specific irriqation pumps either manuallv or with the use of one or more Load
Control Devices.
Prooram Season. The Program Season is the period June 15 through August 15 of each year.
Prooram kW. The Program kW is the demand amount, as measured at the Customer's meter in
kilowatts (kW) durinq the Proqram S , that is multiplied by the applicable incentive amount to
determine the Demand Credit under each lnterruption Option.
Nominated Demand. Nominated Demand
@ Option 3 must declare
elvents.
is the amount of demand that participants under
as available for dispatch during [oad eQontrol
Prooram kWh. The Program kWh is the energy amount, as measured at the Customer's meter
in kilowatt-hours (kwh) durinq the Prooram , that is multiplied by the applicable incentive
amount to determine the Energy Credit under each lnterruption Option.
Variable Prooram kWh. The Variable Program kWh is the demand amount, as measured at the
Customer's meter in kilowatts (kW) multiplied by the hours of interruption for the Metered Service Point
during the Program Season. The Variable Program kWh is multiplied by the applicable variable
incentive payment to determine the Variable Energy Credit under each Interruption Option.
Variable Program kWh = metered kW x hours of interruption during Program Season
Bill Credit. The Bill Credit is the sum of the Demand Credit and the Energy Credit applied to the
Customer's monthly bills for usage that occurs during the calendar months of June, July, and August of
each calendar year. This amount may be prorated for the number of days during the months of June,
July, and August that fall in the Customer's billing cycle to correspond with the Program Season. The
Bill Credit amount may be applied directly to participating Customers' bills or provided in the form of a
check.
Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly
Demand Credit is calculated by multiplying the Program kW by the demand-related incentive amount
for the 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, and August of
each year. This amount may be prorated for the number of days during the months of June, July, and
August that fall in the Customer's billing cycle to correspond with the Program Season.
IDAHO
lssued per Order No. 32776
Effective - Apriue1r 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
Idaho Power Company Fifthsixth Revised Sheet No. 23-2
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-2
Demand Credit = Program kW x demand-related incentive amount
IDAHO
lssued per Order No. 3e776
Effective - ApriugruAry 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-3
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-3
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
DEFI N !TIONS (Continued)
Enerov Credit. The Energy Credit is an energy-based financial incentive provided in the form of
a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Energy
Credit is calculated by multiplying the Program kWh by the energy-related incentive amount for the
lnterruption Option selected by the Customer. The Energy Credit will be included on the Customer's
monthly bills for usage that occurs during the calendar months of June, July, and August of each year.
This amount may be prorated for the number of days during the months of June, July, and August that
fall in the Customer's billing cycle to correspond with the Program Season.
Energy Credit = Program kWh x energy-related incentive amount
Variable Enerov Credit. The Variable Energy Credit is an energy-based financial incentive
provided for the Metered Service Point enrolled in the Program. The Variable Energy Credit is
calculated by multiplying Variable Program kWh by the energy-related incentive amount for the
lnterruption Option selected by the Customer. The Variable Energy Credit is paid in the form of a check
no later than 45 days after the Program Season. This amount may be prorated for the number of days
during the months of June, July, and August that fall in the Customer's billing cycle to correspond with
the Program Season.
Variable Energy Credit = Variable Program kWh x variable energy-related incentive amount
INTERRUPTION OPTIONS
@
Undertne@options,theCompanywilldispatchremotelyservice
interruptions to specified irrigation pumps any Monday through Saturday during the Program Season
between the hours of 1:00 P.M. and 8:00 P.M. Mountain Daylight Time (MDT), excluding Jufy4holidqyg
(Standard lnterruption). Customers may elect to participate until 9:00 P.M. MDT (Extended
lnterruption) and will receive a larger Variable Energy Credit. Service interruptions may last up to 4
hours per day and will not exceed 15 hours per calendar week and 60 hours per Program Season. The
again-fri Durinq each Proqram Season the Companv will
conduct a minimum of three Load Control Events. Customers participatinq in lnterruption Ootion 1 and
Option 2 mav not receive advance notification of a Load Control Event. Notification will be sent to
Customers under lnterruption Option 1 and Option 2 after the Load Control Event beqins. Customers
participatinq in lnterruption Option 3 will receive advance notification at least 4 hours prior to the Load
Control Event. The Companv will provide notice of a Load Control Event via the followino
communication technolooies: telephone. e-mail andior text messaqe. lf prior notice of a pending [oad
eControl elvent has been sent, the Company may choose to revoke the [oad eQontrolelvent and will
provide notice to Customers
en tne eay et tne sen
IDAHO
lssued per Order No. 32776
Effective - Apriueruegt 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-3
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-3CustomerswhoelecttoparticipateintheProgram@ien-maybeeligible
for one of the following @Options:
IDAHO
lssued per Order No. 3e776
Effective - Apriueruqy 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-4
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu#hFifth Revised Sheet No. 23-4
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMru
(Continued)
I NTERRUPTION OPTIONS (Continued)
OisBatenaUte lnte
Option 1. A dispatchable one-way communication 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 tnis-gispa+€hab+e
Option l_will provide the Company the ability to send a signal that will interrupt or not allow the
associated irrigation pumps to operate during dispatched [oad eControl eEvents. This option
requires that all pumps at the Metered Service Point be controlled.
Under g+spa+enaUe-Option 1, the Program kW will be based upon the monthly
Billing Demand, as measured in kW, for the associated Billing Period. The Program kWh under
this option will be based upon the monthly energy usage, as measured in kWh, for the
associated Billing Period.
Customers selecting gispa+chab+e-Option 1 may opt-out of a [oad eControl
eEvent up to five times per season any-+ime-prior to or during a [oad eQontrol elvent. Each
time a customer chooses to opt-out of aone of the three min [oad e9ontrol elvents a fee
of $05.00 per kW will be assessed based upon the current Billing Period's kW. This ameunt
maf be prerated fer the number ef days during the menths ef June; July; and August that fall in
the Custemer's bil Each time a customer
chooses to opt-out of a Load Control Event after the three minimum Load Control Events a fee
of $1.00 per kW will be assessed based upon the current Billinq Period's kW. The opt-out fee
will not exceed the total Bill Credit for the Prooram Season. Anv opt-out fee will be applied at
the end of the Proqram Season.
Option 2. A dispatchable Load Control Device capable of two-way communication will be
connected to the electrical panel(s) servicing the irrigation pumps associated with the Metered
Service Points enrolled in this Program. The Load Control Device utilized under thisgispa+ohablo-Option L will provide the Company and the Customer remote control and
monitoring of the associated irrigation pumps. Under this option, the Company will use this
technology to send a signal that will interrupt or not allow the irrigation pumps to operate during
dispatched [oad eControl eEvents. This option requires that all pumps at the Metered Service
Point be controlled.
Under gispa+€hab{+Option 2, the Program kW will be based upon the monthly
Billing Demand, as measured in kW, for the associated Billing Period. The Program kWh under
this option will be based upon the monthly energy usage, as measured in kWh, for the
associated Billing Period.
Customers selecting gispa{€habl,e-Option 2 may opt-out of a [oad eControl
elvent up to five times per season any+ime-prior to or during a [oad eQontrol efvent. Eachtimeacustomerchoosestoopt-outof@[oadeQontroleEventsafee
of $e5.00 per kW will be assessed based upon the current Billing Period's kW. This ameunt
iR
IDAHO
lssued per Order No. 32776
Effective - Apn+Jelgery 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-4
Cancels
I.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-4
the Custemer's billing eyele te eerrespend with the Pregram Seasen,trach time a customer
chooses to opt-out of a Load Control Event after the three minimum Load Control Events a fee
of $1.00 per kW will be assessed based upon the current Billinq Period's kW. The opt-out fee
will not exceed the total Bill Credit for the Prooram Season. Anv opt-out fee will be applied at
the end of the Prooram Season.
IDAHO
lssued per Order trle. 32776
Effective - npr*l3lggqf 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company FifthSixth Revised Sheet No. 23-5
Cancels
I.P.U.C. No. 29. Tariff No. 101 FeudhFifth Revised Sheet No. 23-5
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
@
(Continued)
I NTERRUPTION OPTIONS (Continued)
gispatenaOte tnter
Option 3. Metered Service Points with interval metering having more than one pump and at
least 1,000 cumulative HP are eligible for D+spatehabte-Option 3. Under ++s-B+spa+enage
Option 3, eligible Customers have the flexibility to choose which irrigation pumps will be
interrupted during each dispatched [oad eControleEvent. Customers electing this option must
notify the Company of their Nominated Demand prior to June 1 of each year.
Customers selecting gispa+enaUe-Option 3 are required to provide no less than
their Nominated Demand during each [oad eControlelvent. Each time a customer chooses to
provide less than their Nominated Demand during aone of the three min [oad eQontrol
elvents, an opt-out fee of $e5.00 per kW will be assessed on the Nominated Demand not made
available for interruption. This ameunt may be prerated fer the number ef days during the
durinq a Load Control Event. after the three minimum Load Control Events. an opt-out fee of
$1.00 per kW will be assessed on the Nominated Demand not made available for interruption.
The opt-out fee will neverno'!exceed the total Bill Credit for the Proqram Sea . Anv opt-out
fee will be applied at the end of the Proqram Season.
Under gispa+enaUe-Option 3, the Program kW will be based upon the maximum
measured interval demand during the 24-hour period preceding 29:00 PA.M. MDT the day of
the announcement of a [oad eQontrol elvent, minus the average demand during an event, as
measured in kW over applicable load profile metering intervals. This applies to each [oad
eQontrol elvent initiated during a Billing Period. lf there are no [oad eQontroleEvents during a
Billing Period then the Program kW will be the Nominated Demand. The Program kWh under
this option will be based upon a calculated value, as measured in kWh. The Program kWh will
be calculated separately for each Billing Period by multiplying the monthly Program kW by the
ratio of the monthly energy usage to the Billing Demand for the associated Billing Period.
+im€+€E{i€{+
Under the Timer Optien; the Gempany er its representative will install a timer based tead
timers te interrupt speeified irrigatien pumps aeeerding te the Tirnerlnterruptien Optien seleeted
te seleet the lead reduetien day(s) fer eaeh Metered Serviee Peint,
nh^^^^' +^ +h^ l^+^""^+r^^ Q^h^^"|^, A Custerner whe eleGts te reduee the number ef days ef
weekly interruptien ef a Metered Serviee Peint en er after June 15 ef eaeh ealendar year shall
IDAHO
lssued per Order No. 32776
Effective - April&lgery 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221Wesl ldaho Street, Boise, ldaho
ldaho Power Company Fifthgxth Revised Sheet No. 23-5
Cancels
l.P.U.C. No. 29. Tariff No. 101 FeudhFifth Revised Sheet No. 23-5
paylhe Cempany the sum ef $0,00; whieh sum will be ineluded en the Custemer's menthly bill
fellewing the implementatien ef the requested ehange, The eusbmer'e Bill Credit shall be
in that menth the Cuetemer partieipated under eaeh
i
INCENTIVE STRUCTURE
lncentive oavment
fixed oavment anO a
a eill Credit and the
Program SeasonJhe first three Load Control Events will not be subiect to the Variable Enerqv Credit.
fne variaOte oavme
the Program Season an after the first three Load Control Events*
IDAHO
lssued per Order No. 32776
Effective - Apc&lgary 1,2013!
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-6
Cancels
|.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-6
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
I NCENTIVE STRUCTU RE (Continued)W
c
i
TERM OF AGREEMENT AND TERMINATION
Tne term of the Agre
particioation, sha
Comoanv anO snatt a
termination is gl ise
terminated as follo
1 A Crrstomer mav terminate the oarticioation of a Metered Service Point witheut-cenaltv
and avoid the Termination Fee by notifying the Com
Proqram
Season,
2 A Cuqfnmer who terminates the nartieination of a Mefcred Senriee Pnint anwfime
@Uoon terminating
Provisions ot item Z, t
until the following and the aoplicable Termination Fee has been paid in full=
netween .tune tS an ieieng
efitem-+-agever-snatt oav tne Comp
Customer's montnl
Oe ororateO for tne n
Program.
IDAHO
lssued per Order No. 3e776
Effective - Apn{elgq 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
Dispatehable-l ntenu ption Option
Fixed lncentive Pavment Variable lncentive Pavment
lnterruption
Dispa+ehable
Option
Demand Credit
($ per Prooram
ku[)
Enerov Credit
($ per Proqram
kwh)
Standard
!nterruption
Variable Enerqv
Credit
($ per Variable
Prooram kwh)
Extended
lnterruption
Variable Enerqv
Credit
($ per Variable
Prooram kWh)
1 $o5.00 $0.00976 $0.099148 $0.000198
2 $e5.00 $0.00e76 $0.0ee148 $0.00s198
3 $o5.00 $0.00076 $0.000148 $0.009198
ldaho Power Company Fifrhsixth Revised Sheet No.23-6
Cancels
|.P.U.C. No. 29. Tariff No. 101 FeudhFifth Revised Sheet No. 23-6
Terminalion Fees:
Dis'ea*ehebl+lnterruption Ootions 1 and 2: $e500.00 oer Metered Service Point
terminated under I
g. f tnere is eviaen
abilitylojnitiaie_alload eConlrol_eEvent at a Metered Se
to tnat UtetereO Seru
suOiect to eacn of ing:
+im€r{f,t€rfup+i€n€E+i€'r1
llme+€E+i€{+E€mand-C+ed+tM En€rEeY€rcditM
One€ay $o=oe $0=0ee
Twe Days $e=oe $0,0ee
Three Days $e,oe $e€ee
INSTATTATION FEES
An lnstallatien Fee may be applieable depending upen the size' as measured in hersepewer' ef
the irrigatien system asseeiated with a partieipating Metered Serviee Peint, The purpese ef the
lnstallatien Fee is te effset a pertien ef the installatien eests asseeiated with Metered Seryic€ Peints
te+tewins+able,
H€rs€p€we+{HP)9ispa+ehable€pt+en +im€r
Oetien+2 3_t
tes€+han€+HP $o $e N/n $e
Frem 30 te 49 HP $o $o N/n $s
Frem 50 te 74 HP $o $e N/A $s
Frem 75te 99 HP $o $e N/n $e
G"r€€t€r+han4€tHP $e $o N/n $s
Nete: (*) An lnstallatien Fee will net be ass€ssed under Dispatehable Optien 3,
IDAHO
lssued per Order No. 32776
Effective - Apn+Jelgery 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-7
Cancels
!.P.U.C. No. 29. Tariff No. 101 Feu#hFifth Revised Sheet No. 23-7
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
TERM OF AGREEMENT AND TERMINATION (Continued)
TERM EF AGREEMENT
g, lf there is eviden
@+ng*a. The Customer will be required to reimburse the Company for the cost of
replacement or repair of the Load Control Device(s), including labor and other related
costs.
b. An applicable Termination Fee, as provided under item 2, will be applied to the
Customer's monthly billfollowing the termination of participation.
c. The Company will reverse any and all Demand Credits and/or Energy Credits
applied to the Customer's monthly bill(s) for the Metered Service Point as a result of the
Customer's participation in the Program during the current year.
Note: A service disconnection for any reason does not terminate the Agreement.
SPECIAL CONDITIONS
fne orovisions of tn
t-oaO Controt Oevice
emeroency or anv otn
tne Companv. fne prc
Service. Enerov or Demand Charoes associated with a Customer's standard service schedule.
IDAHO
lssued per Order No. 32776
Effective - Apriuellery 1,2013!
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company F+fthsixth Revised Sheet No. 23-8
Cancels
!.P.U.C. No. 29. Tariff No. 101 Feu*hFifth Revised Sheet No. 23-8
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMru
(Continued)
W
+=es_e
Mass memery meters may be installed en a seleet number ef Metered Serviee Peints fer
Pregram menitering and evaluatien purpeses, The sample ef Metered Serviee Peints seleeted fer
tee
Peints that were enrelled in the Dispatehable lnterruptien Optien 1 and 2 and in the Timer lnterruptien
will be paid during the Billing Perieds that inelude June 15' 2013 threugh August 15; 2013 and may be
preratea fer tne nu
in
the Bispatehable lnterruptien Optien 3 during the 20€ Pregram Seasen and are aetive en June 15'
The 2013 Demand Credit will be based en the lesser ef th€ Neminated Demand fer the 2012 Pregram
lnterruptien Optien
M MM
+*27
2 $227
3 *27
+irm€r€E+i€'r1+MM
One Day $0=54
Twe Days $e€4
+hree€avs $H3
IDAHO
lssued per Order No. 32776
Effective - Apriuellery 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fifthsixth Revised Sheet No. 23-8
Cancels
|.P.U.C. No. 29. Tariff No. 101 FeudhFifth Revised Sheet No. 23-8
Uniform lrrigatio ice
Aoptication/noree
THIS AGRFFMFNT Made this dav of
hereinafter called
Customer- whose hillino address is
anO tOnHO POWen COU
Street, goise. ldah
tS ot eacn caenOar y
annuat renewat Oat
worfsneet (Wo*sne*
The Customer desl :
Authorized Contact:
Phone: Cell Phone'
Fax:
ruow, rHeneronr. rn
t. fne Uniform lnioa
Customer anO tne Cu
electric service or
Worksheet
Z. fne Customer unO
Worfsneet is OaseO
amounts are estima iCe
Point(st specifie
an estimateO Bitl ice
Point. fne Aill Cred
sPecifv wnicn UetereO S in
tne Prooram anO tne l
Metered Service Pol lnterruption Ootion 3 the Custom
the Comoanv of ttloml
IDAHO
lssued per Order No. 32776
Effective - Apnuglgq 1,2019!
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company F€udhFifth Revised Sheet No. 23-9
Cancels
LP.U.C. No. 29. Tariff No. 101 ThiCFourth Revised Sheet No. 23-9
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
Uniform lrrioation
Aoplication/Agree
Gontinuedl
g. from time to time
Comoanv, tne Custo
prooertv on wnicn tne e
its reoresentative t
etectrical oanet t
remain-in otace on tne C
Customer soecifio
+. fne Customer unO
Companv snatt, at ion_pumps
at tne UetereO Servl
tnterruotion Ootl
which-a-lload-cConfrpl-eEve nt is sched u led tu
atso unOerstanOs a
tnan one irrigatio
excluding Metered S lnterruption
apfion3.
is
i
65. For the Customer'
Customer tne Oeman
setecteO Ov tne Cu ing
nistorv tor tne Veterc
Uutv, anO nuqust of
Customer's montnl
ororateO for tne montn
UetereO Service Poin
under-the-manuaFl nterruption gOptions, will receive a Bi I
Oavs of Uitting due
6. lf the Customer terminates this Aoreement anvtime between June 15 and Auoust 15 of the
current calendar year while the Metered Service Point(s) are still connected for service the
Customer mav not re-enroll that Metered Service Point into the Proqram until the followinq
calendar vear and the applicable Termination Fee has been paid in full.
Uniferm lrrieatien P iee
IDAHO
lssued per Order No. 32776
Effective - npr*le4gg1y 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company F€'rJ+hFifth Revised Sheet No. 23-10
Cancels
I.P.U.C. No. 29. Tariff No. l0l ThidFourth Revised Sheet No. 23-10
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAMW
(Continued)
Uniform lrrioation Peak Rewards Service
Application/Aq reement
(Continued)
7, lf the eustemer t
net elected Earlv Te
in
that menth that the
that a Metered SeruiG
terminate the parti€
15; Upen terminatl
that Metered Serviee
8, Under the Timer O
number ef davs ef we
calendar vear, the
The Custemer's Bill
reeuests te increas
€a{€nC€+-ve€+,
te initiate a lead e
Metered Service Pein
reimburse the Cemp
includinq laber an
Credits applied te th
eustemer's partiGl
te be censidered pa
7. lf there is evidence of alteration. tamperinq. or otherwise interferino with the Company's abilitv
to initiate a Load Control Event at a Metered Service Point(s). the Aoreement as it applies to
that Metered Service Point will be automaticallv terminated. The Customer will also be required
to reimburse the Companv for all costs of replacement or repair of the Load Control Device(s).
includinq labor and other related costs, pav the Companv the applicable Termination Fee which
sum will be included on the Customer's monthlv bill and the Companv will reverse anv Demand
Credits applied to the Customer's monthlv bill(s) for the Metered Service Point as a result of the
Customer's participation in the Proqram durino the current vear.
IDAHO
lssued per Order No. 32776
Effective - *p*JangAlt 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company F€ufrhFifth Revised Sheet No. 23-10
Cancels
!.P.U.C. No. 29. Tariff No. l0l ThidFourth Revised Sheet No. 23-108. The Companv's Schedule 23. anv revisions to that schedule and/or anv successor schedule are
to be considered part of this Aoreement.
449. This Aoreement and the rates. terms and conditions of service set forth or incorporated herein
and the respective riqhts and obliqations of the Parties hereunder shall be subiect to valid laws
and to the requlatorv authoritv and orders, rules and requlations of the ldaho Public Utilities
Commission and such other administrative bodies havino iurisdiction.
10. Nothinq herein shall be construed as limitino the ldaho Public Utilities Commission from
chanqinq anv terms. rates. charoes. classification of service or anv rules. requlations or
conditions relatinq to service under this Aqreement. or construed as affectinq the riqht of the
Companv or the Customer to unilaterallv make apolication to the Commission for anv such
chanqe.
11. ln anv action at law or equitv under this Aoreement and upon which iudqment is rendered, the
prevailinq Partv. as part of such iudoment. shall be entitled to recover all costs. includinq
reasonable attornevs fees. incurred on account of such action.
12. The Comoanv retains the sole riqht to select and reiect the participants to receive service under
Schedule 23. The Companv retains the sole riqht for its emplovees and its reoresentatives to
install or not install Load Control Devices on the Customer's electrical panel at the time of
installation dependinq on. but not limited to. safefu. reliabilitv. or other issues that mav not be in
the best interest of the Companv, its emplovees or its representatives.
Uniferm lrriest iee
ffi
€€#i4
ien
segeteg gy the €Hs ing
gHlyi snd AHgHst ef
ing
ing
lDAHO
lssued per Order No. 32776
Effective - ApCJgnuary 1,201?4
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company FeudhFifth Revised Sheet No. 23-11
Cancels
!.P.U.C. No. 29. Tariff No. l0l ThirdFourth Revised Sheet No. 23-11
SCHEDULE 23
IRRIGATION PEAK REWARDS
PROGRAM
@
(Continued)
Uniform lrriqation Peak Rewards Service
Application/Ao reement
(Continued)
cenditiens relati
€hange;
13: In anv aetien at lp"E€Yeilfinq-+a# ine
reasenable attern i€)n:
14; The eemBanv reta
Schedule 2S: The Co
install er net inins+a{€+ion+€penCi iR
the best interest o ive€r
153. Under no circumstances shall the Companv or anv subsidiarv. affiliates or parent Companv be
held liable to the Customer or anv other partv for damaqes or for anv loss. whether direct.
indirect. consequential. incidental. punitive or exemplarv resultino from the Proqram or from the
Customer's participation in the Prooram. The Customer assumes all liabilitv and aorees to
indemnifv and hold harmless the Companv and its subsidiaries. affiliates and parent companv
for personal iniurv. includino death. and for oropertv damaqe caused bv the Customer's decision
to oarticipate in the Proqram and to reduce loads.
The Companv makes no warrantv of merchantabilitv or fitness for a particular ourpose with
respect to the Load Control Device(s) and anv and all implied warranties are disclaimed.
(Appropriate Siq natures)
IDAHO
lssued per Order No. 32776
Effective - l,p++fengry 1,20134
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Firstsecond Revised Sheet No. 81-1
Cancels
l.P.U.C. No. 29. Tariff No. 101 OriqinalFirst Revised Sheet No. 81-1
SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAMW
Service under thie i€e
under this sehedu! ien=
PURPOSE
The Residential Air Conditioner Cycling Program is an optional, supplemental service that
permits participating residential Customers an opportunity to voluntarily allow the Company to cycle
their central air conditioners with the use of a direct load control Device installed at their residence.
Customers will receive a m€nth{y-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 Customer's
residence and instructing it to cycle the Central Air Conditioning compressor for a specified length of
time.
Air Conditionino Season is the three menth period that commences on June 415 and continues
through August 341! of each calendar year.
Central Air 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
Customer's residence.
Cvclinq Event is a period during which the Company sends a signal to the Device installed at
the Customer's residence, which instructs the Device to begin AC Cycling.
Device is a direct load control device installed at a Customer's residence that enables the
Company to in+tia{econduc! AC Cycling.
Notification refers to the Customer's indication of intent to initiate or terminate participation in the
Program by either contacting the Company's Customer Service Center, providing written notice or
submitting an electronic Application via the Company's website.
Opt Out is the term used to describe the two times
each Air Conditioning Season in which the Customer may choose to temporarily not participate in AC
Cycling by providing advanced Notification to the Company.
Proqram 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 ldaho where the infrastructure
required to support AC Cycling has been installed and is operational.
IDAHO
lssued per Order No. 32776Effective-@
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company SeeenAl'nircl Revised Sheet No. 81 -2
Cancels
l.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 81-2
SCHEDULE 81
RESI DENTIAL AI R CONDITIONER
CYCLING PROGRAMW
(Continued)
AVAILABILITY
Service under this schedule is available on an optional basis to Customers taking service under
Schedule 1 or Schedule 5 who have Central Air Conditioning located at their residences and live within
the Program Operation Area. 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 limited to, energy usage, residential location,
size of home, or other factors. Customers' Central Air Conditioning equipment must be fully functional
and comply with the National Electric Code (NEC) standards. 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.
TERMS AND CONDITIONS
Upon acceptance into the Program, Customers will be subject to the following terms and
conditions:
1. 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 property to install a Device and, in certain cases, either 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 following its installation.
2. Customers added to the Program during the Air Conditioning Season must be effectively
participating in the Program prior to the 20th day of the month in order to receive an incentive payment
for that initial-month.
3. A Customer may Opt Out of the Program during eaeh
m€nth-€+the Air Cond itioning Season.
4. A Customer may discontinue participation in the Program without penalty by providing
Notification to the Company.
5. lf there is evidence of alteration, tampering, or othenrrrise 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 Customer's participation in the Program.
IDAHO
lssued per Order No. 32776Effective-@
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fir€+Second Revised Sheet No. 81-3
Cancels
l.P.U.C. No. 29. Tariff No. 101 Oriqina+First Revised Sheet No. 81-3
SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAMW
(Continued)
PROGRAM DESCRIPTION
1. At the Company's expense, the Company or its representative will install a Device at the
Customer's residence.
2. A financial incentive of $e5.00 per month for each of the three months of the Air
@une. Julv. and Auqust will be paid to each Customer who successfully
participates in the Program. This incentive will be paid in the form of a credit on the Customer's
monthly bill for each month that the Customer successfully participates in the Program, beginning with
the July bill and ending with the September bill. lncentive payments are limited to one controlled
Central Air Conditioning unit per metered service point. Customer:s who have more than one Central
Air Conditioning unit at a metered service point may participate in the Program. A Device must be
installed at each CentralAir Conditioning unit. However, no additional incentive will be paid.
3. The Company will send a signal to the Device to initiate a Cycling Event. A Cycling
Event may be up to four hours per day on any weekday during the Air Conditioning Season, excludinq
holidavs. 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 4el! hours each men*Fweek and will not exceed a total of 42060 hours per Air
Conditioning Season. Durinq each Air Conditionino Season. the Companv will conduct at least three
Cvclinq Events. Mass memory meters or end-use meters may be installed on some Customers'
residences or Central Air Conditioning units for program evaluation purposes. The residences or
Central Air Conditioning units selected for installation of the meter shall be at the Company's sole
discretion.
SPECIAL CONDITIONS
The Company is not responsible for any consequential, incidental, punitive, exemplary or
indirect damage to the participating Customer or third parties that results from AC Cycling, from the
Customer's participation in the Program, or of Customer's efforts to reduce peak energy use while
participating in the Program.
The Company makes no warranty of merchantability or fitness for a particular purpose with
respect to the Device and any and all implied warranties are disclaimed.
The Company shall have the right to select the AC Cycling schedule and the percentage of
Customers' Central Air Conditioning systems to cycle at any one time, up to 100Vo, at its sole
discretion.
The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer's load for a system emergency or any other time that a Customer's service is interrupted by
events outside the control of the Company. The provisions of this schedule will not affect the
calculation or rate of the regular Service or Energy Charges associated with a Customer's standard
service schedule.
IDAHO
lssued per Order No. 32776
Effective - AFril-{.404{}Januarv 1. 2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho
ldaho Power Company Fi{€tsecond Revised Sheet No. 81-3
Cancels
I.P.U.C. No. 29. Tariff No. 101 OrieinalFirst Revised Sheet Nos. 81-3
S€HEDTJIFE+
RESIBENTIAT AlR CO
EYCTING PROGRNM
(SUSPENDED)
€en+inueA)
trrr^rhrrr+" Custemers partieipating in the Pregram en Mareh 31' 2013 and whe maintain an
^^a 2 arrr ^'^dr+ The 2013 Bill Credit will be $1,00 per menth fer eaeh ef the three menths Junet
fer eaeh menth that the Custemer is enrelled i+ the Pregram, beginning with the July bill and ending@
,-,,6+^m^' p^^,,^-+^,-l n^,,i^^ p^m^,,^r nny custemer partieipating in the pregram en er aftgr
IDAHO
lssued per Order No. 32776
Effective - AFrif{.4043Januarv 1. 2014
lssued by IDAHO POWER COMPANY
Gregory W. Said, Vice President, Regulatory Affairs
1221West ldaho Street, Boise, ldaho