20231027Motion for Approval of Stipulations and Settlement.pdf

LISA D. NORDSTROM
Lead Counsel
[e-mail]
October 27, 2023
VIA ELECTRONIC FILING/HAND DELIVERY
Jan Noriyuki, Secretary
Idaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg 8,
Suite 201-A (83714)
PO Box 83720
Boise, Idaho 83720-0074
Re: Case No. IPC-E-23-11
Idaho Power Company’s General Rate Case
Dear Ms. Noriyuki:
Attached for electronic filing is Idaho Power Company’s Motion for Approval of
Stipulation and Settlement in the above-entitled matter.
In addition, please find attached the Direct Testimony of Timothy E. Tatum filed in
support of the Stipulation. A Word version of the testimony will also be sent in a separate
email for the convenience of the Reporter.
If you have any questions about any of the aforementioned documents, please do
not hesitate to contact me.
Very truly yours,
Lisa D. Nordstrom
LDN:sg
Enclosures
RECEIVED
Friday, October 27, 2023 2:23:46 PM
IDAHO PUBLIC
UTILITIES COMMISSION

MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 1

LISA D. NORDSTROM (ISB No. 5733)
DONOVAN E. WALKER (ISB No. 5921)
MEGAN GOICOECHEA ALLEN (ISB No. 7623)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]
[e-mail]

Attorneys for Idaho Power Company

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO INCREASE ITS RATES
AND CHARGES FOR ELECTRIC
SERVICE IN THE STATE OF IDAHO
AND FOR ASSOCIATED REGULATORY
ACCOUNT TREATMENT.

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CASE NO. IPC-E-23-11

MOTION FOR APPROVAL OF
STIPULATION AND SETTLEMENT

COMES NOW, Idaho Power Company (“Idaho Power” or “Company”), the Idaho
Public Utilities Commission (“IPUC” or “Commission”) Staff, and intervenors in this
proceeding that have agreed to the settlement as noted herein (collectively referred to
as the “Parties”), and hereby move the Commission pursuant to Commission Rules of
Procedure1 274-276 for an Order accepting the Stipulation and Settlement
(“Stipulation”) filed herewith. This Motion is based on the following and the Direct
Testimony of Timothy E. Tatum filed contemporaneously herewith:

1 Hereinafter cited as RP or “Procedural Rule”.
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 2
1.On June 1, 2023, Idaho Power filed an Application in this case seeking
authority to increase the Company’s adjusted base revenue an average of 8.61 percent.
If approved, the Company’s revenues would have increased approximately $111 million
annually. Idaho Power proposed that the rate increase be spread in varying degrees
among all major customer groups and special contract customers. The Company
requested that new rates become effective on January 1, 2024, which is the end of the
statutory period set forth in Idaho Code § 61-622(4) and Procedural Rule 123.03. To
effectuate review of the Company’s request, the Commission suspended the effective
date of the proposed rates for a period of thirty (30) days plus five (5) months from July
1, 2023, in Order No. 35825.
2. Petitions to intervene in this proceeding were filed by Clean Energy
Opportunities for Idaho, the Industrial Customers of Idaho Power, the City of Boise,
Idaho Irrigation Pumpers Association, Inc., Micron Technology, Inc., the Federal
Executive Agencies, the Idaho Conservation League, NW Energy Coalition, IdaHydro,
and Walmart Inc. By various orders, the Commission granted these interventions. IPUC
Order Nos. 35823, 35840, 35850, 35867, and 35902.
3. The Parties consulted informally in July to devise a proposed schedule for
completing discovery, filing testimony, and holding hearings in this proceeding. The
Parties agreed to engage in settlement discussions in accordance with RP 272 with a
view toward resolving the issues in this case. The Parties conducted settlement
discussions on September 18 and October 4-5, 2023.
4. Based on the settlement discussions, all Parties have agreed to resolve
and settle all the issues in the case. A copy of the signed Stipulation evidencing that
settlement is enclosed as Attachment No. 1. If the Stipulation is approved, the
Company’s overall adjusted base revenues will increase by $54.7 million annually for an
average increase of 4.25 percent.
5. For settlement purposes and subject to Commission approval, the Parties
agree that the revenue requirement increase contemplated by the Stipulation should be
recovered by implementing tariffs in conformance with those in Attachment No. 2, which
are intended to effectuate the settlement and incorporate other changes that have been
approved by the Commission as of the date of this filing. The Company will make a
compliance filing with final tariff sheets at the conclusion of this case as ordered by the
Commission and incorporating any changes in other dockets subsequently approved
by the Commission.
6. The Parties recommend that the Commission grant this Motion and accept
and approve the Stipulation in its entirety, without material change or condition,
pursuant to RP 274 and 276.
7. Technical hearings are scheduled to take place November 28 – December
1, 2023. Idaho Power and the Commission Staff each intend to present live testimony
supporting this Motion and recommending approval of the Stipulation. Other Parties
may choose to present live supporting testimony as well. As noted in paragraph 29 of
the Stipulation, all of the Parties agree that the Stipulation is in the public interest and
represents a fair, just, and reasonable compromise of the issues in this proceeding.
NOW, THEREFORE, the Parties respectfully request that the Commission issue
a final order in Case No. IPC-E-23-11:
1. Granting this Motion and accepting Attachment No. 1, the Stipulation, in its
entirety, without material change or condition;
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 3
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 4
2.Authorizing the Company to implement revised tariff schedules designed
to recover $54.7 million in additional annual revenue from its Idaho jurisdiction
consistent with the terms of the Stipulation; and
3. Authorizing that the revised tariff schedules be made effective January 1,
2024.
Respectfully submitted this 27th day of October 2023.
LISA D. NORDSTROM
Attorney for Idaho Power Company
DONOVAN E. WALKER
Attorney for Idaho Power Company
MEGAN GOICOECHEA ALLEN
Attorney for Idaho Power Company

MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 5

CERTIFICATE OF SERVICE

I HEREBY CERTIFY that on the 27th day of October 2023, I served a true and
correct copy of Idaho Power Company’s Motion for Approval of Stipulation and
Settlement upon the following named parties by the method indicated below, and
addressed to the following:

Commission Staff
Dayn Hardie
Chris Burdin
Deputy Attorney General
Idaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg No. 8
Suite 201-A (83714)
PO Box 83720
Boise, ID 83720-0074

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Clean Energy Opportunities for Idaho
Kelsey Jae
Law for Conscious Leadership
920 N. Clover Dr.
Boise, ID 83703
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Courtney White
Mike Heckler
Clean Energy Opportunities for Idaho
3778 Plantation River Drive, Suite 102
Boise, ID 83703

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Industrial Customers of Idaho Power
Peter J. Richardson
Richardson Adams, PLLC
515 N. 27th Street
Boise, Idaho 83702

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MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 6

Dr. Don Reading
280 Silverwood Way
Eagle, Idaho 83616

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Idaho Irrigation Pumpers Association,
Inc.
Eric L. Olsen
ECHO HAWK & OLSEN, PLLC
505 Pershing Avenue, Suite 100
P.O. Box 6119
Pocatello, Idaho 83205

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Lance Kaufman, Ph.D.
2623 NW Bluebell Place
Corvallis, OR 97330
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Micron Technology, Inc.
Austin Rueschhoff
Thorvald A. Nelson
Austin W. Jensen
Holland & Hart, LLP
555 Seventeenth Street, Suite 3200
Denver, Colorado 80202

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Jim Swier
Micron Technology, Inc.
8000 South Federal Way
Boise, Idaho 83707
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MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 7
City of Boise
Ed Jewell
Darrell Early
Boise City Attorney’s Office
150 N. Capitol Blvd.
Boise, ID 83701
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Wil Gehl
Boise City Dept. of Public Works
150 N. Capitol Blvd.
P.O. Box 500
Boise, Idaho 83701-0500
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Idaho Conservation League
Matthew Nykiel
Idaho Conservation League
710 N. 6th Street
Boise, Idaho 83702
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Brad Heusinkveld
Idaho Conservation League
710 N. 6th Street
Boise, Idaho 83702
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IdaHydro
C. Tom Arkoosh
Arkoosh Law Offices
913 W. River Street, Suite 450
P.O. Box 2900
Boise, Idaho 83701
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Federal Executive Agencies
Peter Meier
Paige Anderson
Tanner Crowther
U.S. Department of Energy
1000 Independence Ave., S.W.
Washin ton, DC 20585
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MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT - 8
Dwight Etheridge
Exeter Associates
5565 Sterrett Place, Suite 310
Columbia, MD 21044
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NW Energy Coalition
F. Diego Rivas
1101 8th Ave
Helena, MT 59601
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Walmart Inc.
Norman M. Semanko
Parsons Behle & Latimer
800 West Main Street, Suite 1300
Boise, Idaho 83702
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Steve W. Chriss
Director, Energy Services
Walmart Inc.
2608 Southeast J Street
Bentonville, Arkansas 72716
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Justina A. Caviglia
Parsons Behle & Latimer
50 West Liberty Street, Suite 750
Reno, NV 89502
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Stacy Gust Regulatory Administrative
Assistant

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-23-11

IDAHO POWER COMPANY

ATTACHMENT NO. 1

STIPULATION FOR SETTLEMENT

STIPULATION AND SETTLEMENT - 1
LISA D. NORDSTROM (ISB No. 5733)
DONOVAN E. WALKER (ISB No. 5921)
MEGAN GOICOECHEA ALLEN (ISB No. 7623)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]
[e-mail]

Attorneys for Idaho Power Company

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO INCREASE ITS RATES
AND CHARGES FOR ELECTRIC
SERVICE IN THE STATE OF IDAHO
AND FOR ASSOCIATED REGULATORY
ACCOUNTING TREATMENT.

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CASE NO. IPC-E-23-11

STIPULATION AND SETTLEMENT

This Stipulation and Settlement (“Stipulation”) is entered into by and among Idaho
Power Company (“Idaho Power” or “Company”), the Staff of the Idaho Public Utilities
Commission (“Staff”), and all intervenors in this docket: Clean Energy Opportunities for
Idaho (“CEO”), Industrial Customers of Idaho Power (“ICIP”), City of Boise, Idaho
Irrigation Pumpers Association, Inc. (“IIPA”), Micron Technology, Inc. (“Micron”), Federal
Executive Agencies (“FEA”), Idaho Conservation League (“ICL”), NW Energy Coalition
(“NWEC”), IdaHydro, and Walmart, Inc. These entities are referred to individually as a
“Party” or collectively referred to as the “Parties.”
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 2
I. INTRODUCTION
1. The terms and conditions of this Stipulation are set forth herein. If the
Stipulation is approved, the Company’s overall retail revenue will increase by $54.7 million
annually for an average increase of 4.25 percent, which is net of a Power Cost Adjustment
(“PCA”) decrease of $168.3 million and a reduction to annual Energy Efficiency Rider
collection of $3.5 million. The Parties agree that this Stipulation represents a fair, just, and
reasonable compromise of the issues in this proceeding and that this Stipulation is in the
public interest. The Parties maintain that the Stipulation and its acceptance by the Idaho
Public Utilities Commission (“IPUC” or “Commission”) represent a reasonable resolution of
all issues identified in this matter. Therefore, the Parties recommend that the Commission,
in accordance with Commission Rule of Procedure1 274, approve the Stipulation and all of
its terms and conditions without material change or condition.
II. BACKGROUND
2. On June 1, 2023, Idaho Power filed an Application in this case seeking
authority to increase the Company’s Idaho jurisdictional retail revenue an average of 8.61
percent. If the Company’s initial proposal had been approved, the Company’s revenues
would have increased approximately $111 million annually. Idaho Power proposed
spreading the rate increase to varying degrees among all customer classes and special
contract customers. The Company requested that new rates become effective on
January 1, 2024, which is the end of the statutory period set forth in Idaho Code § 61-
622(4) and RP 123. Pursuant to Procedural Rule 125, Idaho Power notified customers
of the requested rate increase via press release, customer notices mailed to individual
customers, and personal contact with some customers.

1 Hereinafter cited as RP or “Procedural Rule”.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 3
3. To facilitate review of the Company’s request, on June 23, 2023, the
Commission designated the proceeding as a general rate case pursuant to Procedural
Rule 124 and notified the public in Order No. 35825 that the Commission may make
decisions addressing the Company’s revenue requirement, rates, charges, and service
to its Idaho retail customers. It also suspended the effective date of the proposed rates
for a period of thirty (30) days plus five (5) months from July 1, 2023.
4. Petitions to intervene in this proceeding were filed by CEO, ICIP, the City of
Boise, IIPA, Micron, FEA, ICL, NWEC, IdaHydro, and Walmart Inc. By various orders,
the Commission granted these interventions. IPUC Order Nos. 35823, 35840, 35850,
35867, and 35902.
5. The Parties consulted informally in July to devise a proposed schedule for
completing discovery, filing testimony, and holding hearings in this proceeding. The
Parties also agreed to engage in settlement discussions in accordance with RP 272 with
a view toward resolving the issues in this case. All Parties attended, whether in person
or virtually, settlement discussions on September 18 and October 4-5, 2023.
6. Based upon the settlement discussions among the Parties, as a
compromise of the positions in this case, and for other consideration as set forth below,
the Parties agree to the following terms:
III. TERMS OF THE STIPULATION AND SETTLEMENT
A. Revenue Requirement
7.The Parties agree that Idaho Power shall be allowed to implement revised
tariff schedules that will increase annual Idaho jurisdictional retail revenues by $54.7
million, or 4.25 percent, effective January 1, 2024. The Parties further agree that the
$54.7 million increase represents a compromise of the revenue requirement positions in
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 4
the case for the purpose of settlement and that the agreed upon amount should be
approved by the Commission in its entirety without further adjustment. In determining the
$54.7 million additional revenue requirement, the Parties agree on certain revenue
requirement adjustments to the Company’s filed case as summarized in the table below
and further described in the paragraphs that follow. It should be noted that the adjustments
detailed in this Stipulation do not reflect any Party’s endorsement of the underlying
methodology and should not be construed as precedent in any subsequent proceeding
before the Commission.
Summary of Stipulated Revenue Requirement Adjustments
Fi ures reflect Idaho Jurisdictional Amounts
Filed Net Revenue Increase: $111,304,981
Stipulated Adjustments Adjustment Impact Net Rate
Chan e
1. Cost of Capital
a. Rate of Return $23,461,105 $87,843,876
2. Rate Base
b. Test Year Methodolo Ad ustments $8,294,557 $79,549,319
c. Batter Au mentation $2,273,749 $77,275,569
3. Expenses
d. Emplo ee Housin $136,485 $77,139,084
e. Lon -Term Pa at Risk $5,448,325 $71,690,760
f. General Labo $8,961,081 $62,729,679
. Uncollectible Expenses $1,629,964 $61,099,715
h. Miscellaneous d ustments $1,365,132 $59,734,583
i. Non-Specific Reduction $4,195,215 $55,539,368
4. Deferrals and Mechanisms
j. Low Income Ener Assistance $1,324,853 $54,214,516
k. Removal of WRAP Expenses $585,182 $53,629,334
l. Intervenor Fundin Amortization $235,319 $53,394,015
m. Wildfire Removal and Amortization $1,617,743 $55,011,758
n. Net Power Suppl Expense $291,972 $54,719,786

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 5
1. Cost of Capital
(a) Cost of Capital. The parties agree to a 9.6 percent return on equity
(“ROE”) and a 7.247 percent overall rate of return (“ROR”) based on a non-specified cost
of debt and capital structure, applied to an authorized Idaho jurisdictional rate base of
$3,816,351,478.
2. Rate Base
(b) Test Year Rate Base Methodology Adjustments. Parties agree to
reduce the test year revenue requirement by $8,294,557 to reflect the removal of certain
plant held for future use items and annualizing adjustments associated with certain large
capital projects.
(c) Battery Augmentation. Parties agree to reduce the test year revenue
requirement by $2,273,749 to remove the revenue requirement related to battery
augmentation. To offset the revenue impact of removing the battery-related revenue
requirement, Idaho Power will be provided the opportunity to accelerate the amortization of
additional accumulated deferred investment tax credits (“ADITC”) as further discussed in
the Section C below.
3. Expenses
(d) Employee Housing. Idaho Power will apply an imputed $136,485 rent
revenue credit to completely offset the revenue requirement for certain Company-provided
employee housing.
(e) Long-Term Pay at Risk Payments. Parties agree to remove from the
test year revenue requirement $5,448,325 of long-term pay at risk payments for officers
and senior managers tied to the financial performance of the Company.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 6
(f) General Labor. Parties agree to reduce the test year revenue
requirement by $8,961,081 to reflect the removal of a portion of the 2022 general wage
adjustment (“GWA”) and the entirety of the 2024 GWA.
(g) Uncollectible Expenses. Parties agree to reduce the test year revenue
requirement by $1,629,964 to remove certain test year uncollectible debt expense.
(h) Miscellaneous Administrative and General Expense Adjustments. For
settlement purposes Parties agree to adjust a portion of the test year operating expenses
related to the following cost categories: 1) billing inserts ($111,560), 2) injuries & damages
($73,682), 3) Company airplane flights & maintenance ($76,083), 4) advertising ($79,043),
5) credit card expenses ($342,291), 6) unrealized benefits of the Company’s mobile
application ($87,615), and 7) board of directors’ compensation and expenses ($594,858).
The net effect of these adjustments decreases the overall test year revenue requirement by
$1,365,132. The adjustments described in this paragraph serve to reduce the level of
allowed recovery for each respective cost category, but do not entirely eliminate cost
recovery for any individual cost category nor do they establish precedent for any future
proceedings.
(i) Non-Specific Adjustment. Parties agree to an additional non-specific
adjustment to the overall revenue requirement to arrive at the stipulated revenue increase
of 4.25 percent, or approximately $54.7 million. Net of all other adjustments, a non-specific
reduction of $4,195,215 is required to arrive at the stipulated rate increase. The non-specific
reduction reflects a portion of the value of other adjustments that Staff or Intervenors believe
should be made to the test year revenue requirement to arrive at just and reasonable rates,
but which are not specifically identified as part of this Stipulation.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 7
4. Deferrals / Mechanism-Related Adjustments
(j) Energy Efficiency Rider Funded Activities. Consistent with the
Company’s application, approximately $3.5 million in ongoing Energy Efficiency Rider
(“Rider”)-funded labor costs will be transferred into base rates, while otherwise
maintaining the same level of annual demand-side management (“DSM”) funding as
measured in dollars that exists today, warranting a decrease to the level of annual
collection through Schedule 91, Energy Efficiency Rider, from the current 3.1 percent of
base revenue to 2.35 percent of base revenue. Additionally, the Parties agree that the
existing obligations for $1.2 million for income-qualified weatherization and $125,000 for low-
income education are to be moved from base rate revenue requirement to recovery through
the Rider, resulting in a reduction to the base rate revenue requirement of $1,324,853. The
Company commits to work with Staff and the Community Action Partnership agencies to
develop implementation and ongoing administration details, including funding levels, for
both programs, which could be presented for Commission approval in Idaho Power’s next
demand-side management prudence filing or other compliance filing.
(k) Western Resource Adequacy Program (“WRAP”). To reflect the
deferral of WRAP expenses authorized by Commission Order No. 35920, the Parties
agree to reduce the test year revenue requirement by the Idaho jurisdictional share of
$585,182.
(l) Intervenor Funding Amortization. The Parties agree to amortize
intervenor funding over seven years, resulting in a test year revenue requirement
reduction of $235,319.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 8
(m) Wildfire Expense Removal, Deferral, and Amortization. Various
wildfire-related costs that constituted one-time expenditures that will not continue in the
future were removed from the Company’s revenue requirement, reducing the revenue
requirement by $328,055. Vegetation management and other wildfire expenses included
into base rates will be $26,080,688.2 Incremental vegetation management costs above
the 2022 actuals amount of $24,848,8753 will continue to be deferred through the earlier
of the Company’s next general rate case or 2025. Expenses for the Covered Wire
Evaluation pilot and the Vegetation Management Satellite and Aerial Patrols pilot are to
be deferred through 2025. Incremental insurance above the 2022 actuals amount of
$14,489,412 will continue to be deferred through the earlier of Idaho Power’s next general
rate case or 2025. The Company’s test year revenue requirement was increased by
$1,945,798 to reflect the amortization of the total balance of the wildfire deferral reduced
by $400,000 of grants received for the Fire Mesh and Vegetation Management Satellite
projects over a 7-year period.
(n) Net Power Supply Expense (“NPSE”). An adjustment was made to
update the surplus sales modeling assumption related to wheeling that reduces filed
system NPSE by $5,651,170. Net of the PCA Transfer Adjustment, this results in a net
reduction to the Company’s revenue requirement of $291,972.

2 The $26,080,688 figure reflects total expenses of $26,408,743 as provided in the Company’s Confidential
Attachment to Staff’s Request for Production No. 225 less the $328,055 of specific items removed from
inclusion in this case per the terms of this Stipulation. 

3 This cost baseline is established to track incremental costs of maintaining a three-year vegetation
management cycle and enhanced practices for distribution Red and Yellow Risk-Zones.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 9
B. Cost-of-Service, Rate Spread, and Rate Design

8. Cost-of-Service. The Parties do not agree on any particular cost-of-service
methodology and this Stipulation does not request that the Commission approve a particular
cost-of-service methodology. The Company’s filed cost-of-service methodology, updated
to reflect the settled revenue requirement, has been utilized on a limited basis to determine
Fixed Cost Adjustment (“FCA”) rates; the Sales Based Adjustment Rate (“SBAR”) used in
the PCA; Schedule 20, Speculative High-Density Load Interruption Compensation; special
contract rates (except for Schedule 30 discussed further in paragraph 10); and optional
service offerings including Schedules 31, 45, 46, and 62.
9. Rate Spread. The Parties agree that the above-described $54.7 million net
revenue increase should be recovered by implementing tariffs in conformance with the
attached Stipulation Exhibit No. 1. The rate spread was generally developed using a
method to increase the rates for each customer class by a factor at least 0.5 times, but not
more than 1.3 times, the overall 4.25 percent increase, with no increase for any customer
class above 120 percent of the cost-of-service index.
10. Rate Design. For settlement purposes, the Parties agree to the rate design
and tariff provisions included in Attachment No. 2 to the Motion for Approval of Stipulation
(“Motion”) filed contemporaneously herewith. The Parties note the following terms, as
included in Attachment No. 2 and Stipulation Exhibit No. 2, which details the rate calculations
for the various schedules, that differ from the Company’s Application. First, in determining
the individual rates for residential Schedules 1, Residential Service Standard Plan, and 6,
Residential Service On-Site Generation, the Parties agree to use the customer billing
determinants as proposed by the Company in this case but maintain the current
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 10
percentage differential between each block. Second, the Parties agree the residential
Service Charge will increase from $5 per month to $10 per month on January 1, 2024, and
to $15 per month on January 1, 2025. Third, the small general Service Charge will
increase from $5 to $25 per month on January 1, 2024. Fourth, a summer mid-peak
period from 3 p.m. to 7 p.m. is added to residential time-of-use (“TOU”) offerings contained
in Schedules 5, Residential Service Time-of-Use Plan, and 6, Residential Service On-Site
Generation, to generally align with Schedules 9, Large General Service, and 19, Large
Power Service as defined in the respective tariff schedules included in Attachment No. 2
to the Motion. Fifth, the revenue requirement allocated to Schedule 30, U.S. Department
of Energy Special Contract, will be effectuated by setting the demand charge at $9.75/kW
(a 14.71% increase from the current demand charge) and the energy charge at
$0.040951/kWh (a 37.84% increase from the current energy charge). Sixth, the Schedule
8 tariff sheet will be updated to reflect the inclusion of September as part of the summer
season as reflected in Attachment No. 2 to the Motion.
11. Generation Interconnection Charges. The monthly operations and
maintenance (“O&M”) charge in Schedule 72, Generator Interconnections to PURPA
Qualifying Facility Sellers, will be updated in the future to reflect current operating metrics
and assumptions, in conjunction with the informal proceeding described in paragraph
13(b) below.
12. Rate Effective Date. The Parties request that the Commission issue an
Order approving the agreed-upon rates contained in this Stipulation to become effective
on January 1, 2024.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 11
13. Separate Informal Proceedings. To facilitate further investigation and
participation, the Parties agree that:
(a) CEO will coordinate and lead two series of workshops. The first
workshop series will address evaluating the feasibility of implementing a revenue neutral bill
protection mechanism to encourage participation for residential customers taking service on
a TOU schedule. This first series of workshops will conclude by February 29, 2024. The
second series of workshops will address three topic areas based upon analysis provided by
CEO and others: 1) class cost-of-service study methodology and analysis including
development of an “Hourly Informed Class Cost of Service (CCOS)” methodology that
assesses what resources are used to serve system load in each hour of the test year, the
cost of those resources in each hour (including analysis of impacts of transmission &
distribution functionalization, financing cost allocations, and hydrogeneration forecasting),
and how those costs are associated with customer load in each hour (to be used for
comparison to the one observation per month 12 Coincident Peak (“CP”)/4CP CCOS
methodology used in Case No. IPC-E-23-11”), 2) a TOU option for irrigators, and 3) TOU
concerns and opportunities.
Idaho Power will participate in and support these workshops by making best
efforts to accommodate requests for effectuating model runs based on input changes
provided by Parties and by working with Parties to resolve any issues relating to the use and
disclosure of confidential Company data needed for the workshops. Additionally, the
Company will potentially provide a meeting space for the workshops.
The Parties will strive to complete the second series of workshops by
December 31, 2024. If the workshops have not been completed by the time the Company
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 12
files notice of an intent to file its next general rate case, any remaining workshop schedule
will be vacated. In that event, Parties will present their respective positions on issues
discussed in the workshops, including the Hourly Informed CCOS methodology and
implications for TOU pricing for the Commission’s consideration in the general rate case.
(b) IdaHydro will initiate and meet with Idaho Power to discuss Qualified
Facility O&M charges. Execution of, and agreement to this Stipulation and Settlement is
without prejudice to any Parties’ ability to bring a separate action before the Commission
related to O&M charges in Schedule 72.
C. Non-Revenue Stipulated Agreements

14. Coal-Fired Plant Investments. The Parties agree that Idaho Power’s share of
all capital expenditures at the jointly owned Jim Bridger Power Plant (“Bridger”) and North
Valmy Power Plant (“Valmy”) through year-end 2022 were prudently incurred. The
stipulated rate increase resulting from this case reflects the full level of collection related to
previously authorized coal-related cost recovery for the Bridger plant.
15. Capital Investments. At the time of this Stipulation, Staff had yet to complete
its review of capital projects included in the test year rate base. Except as otherwise noted
in this Stipulation, all capital projects included in the Company’s test year are presumed to
be prudently incurred as Staff continues its plant investment review. Staff agrees to update
the Company on its progress toward completing its review by November 15, 2023, and
commits to fully complete its plant investment review by December 1, 2023. To the extent
Staff identifies potential prudence concerns, it will identify specific plant investments to be
the subject of further prudence review in the Company’s next general rate case. Also, Idaho
Power and Staff commit to discuss capital project review options and documentation
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 13
generally, and specifically for the Company’s partnered plants, to establish a framework for
future prudence reviews.
16. Revenue Sharing Mechanism. Since 2009, the Company has been subject
to an ADITC / Revenue Sharing Mechanism, which was established by Order No. 30978 in
Case No. IPC-E-09-30 and modified and extended by Order No. 32424 in Case No. IPC-E-
11-22, Order No. 33149 in Case No. IPC-E-14-14, and Order No. 34071 in Case No. GNR-
U-18-01, that includes provisions for the accelerated amortization of ADITC to help achieve
a minimum specified percent Idaho-jurisdiction return on year-end equity (“Idaho ROE”),
currently set at 9.4 percent. The mechanism also provides for the potential sharing between
Idaho Power and Idaho customers of Idaho jurisdictional earnings in excess of a 10.0
percent Idaho ROE. Under the current mechanism, the ADITC and sharing thresholds are
to be reset at a general rate case to align the sharing threshold with the newly-authorized
ROE and the threshold for use of accelerated amortization of ADITC if the Company’s Idaho
jurisdictional ROE falls below 95 percent of the authorized ROE.
17. Under this Stipulation, the ADITC Revenue Sharing Mechanism is modified to
include an additional amount of Investment Tax Credits (“ITC”) equal to the incremental ITC
generated from the Company’s investment in the 2023 battery storage projects, including
augmentation costs. Further, the Parties agree that the maximum allowed annual
accelerated amortization of ADITC, currently set at a $25 million cap, is removed. Effective
January 1, 2024, potential revenue sharing between Idaho Power and Idaho customers of
Idaho-jurisdictional earnings will occur if earnings are in excess of a 9.6 percent Idaho ROE.
Under this Stipulation, all revenue sharing will be implemented through the PCA rather than
a portion offsetting customer-funded pension obligations, which is what occurs under the
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 14
current mechanism structure. The new minimum-specified Idaho ROE is set at 95 percent
of the stipulated 9.6 percent, or 9.12 percent.
18. Power Cost Adjustment (“PCA”). For purposes of calculating the PCA, the
new level of base system NPSE is $484,907,243. This base level of NPSE includes the
transfer of $168.3 million base level NPSE from the PCA to base rates. Stipulation Exhibit
No. 3 attached hereto details the individual PCA component amounts by Federal Energy
Regulatory Commission account that have been agreed upon by the Parties. Schedule
55, Power Cost Adjustment, will be modified effective January 1, 2024, to reflect this
transfer of NPSE recovery to base rates.
19. Third Party Wheeling Tracking. Parties agree that the Idaho jurisdictional
amount of $46,361,643 in third-party point-to-point wheeling revenues will serve as the
baseline for potential future annual tracking of these revenues following discussions
between the Parties and any necessary filings with the Commission.
20. Radial Transmission Line Analysis. Idaho Power commits to notify parties
and work with Staff and interested Parties to discuss an evaluation of the Company’s
transmission system related to radial transmission lines, including 1) the potential
evaluation of the impact to Idaho customers of designating certain lines as distribution
and assigning them on a situs basis, 2) the shifting of costs and revenue between
wholesale and native load customers, and 3) impacts and changes the Company would
have to make to implement any modifications.
21. Test Year Sales Methodology for Future General Rate Cases. Idaho Power
commits to hold discussions with Staff regarding test year sales derivation methodology
prior to the filing of the Company’s next general rate case.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 15
22. Fixed Cost Adjustment (“FCA”). To reflect the change in monthly Service
Charge for the Residential and Small Commercial customer classes, the FCA’s baseline
in Schedule 54, Fixed Cost Adjustment, is set at $10 per month for Residential in 2024
and $15 per month in 2025, and $25 per month for Small General Service. The fixed
costs per customer (“FCC”) and fixed costs per energy (“FCE”) effective January 1, 2024,
are included in Stipulation Exhibit No. 4 for the respective FCA-applicable customer
classes.
23. Sales Based Adjustment Rate (“SBAR”). In determining the agreed-upon
SBAR to be applied in the Company’s PCA, the Parties agree to use Idaho Power’s filed
class cost-of-service methodology to determine the generation-related Idaho jurisdictional
revenue requirement that has been classified as energy-related. The resulting SBAR of
$30.90 per megawatt-hour was developed using 2023 normalized Idaho test year retail
sales in the amount of 14,907,835 megawatt-hours as proposed by the Company in this
case. Stipulation Exhibit No. 5 to the Stipulation details the derivation of the agreed upon
SBAR that is to become effective on the date that the Company’s new base rates become
effective.
24. Natural Gas-Fired Plant Maintenance. The Parties agree that Idaho Power
should be authorized to defer and amortize annual differences between certain periodic
maintenance costs at the Company’s natural gas-fired power plants. Idaho Power will defer
these amounts to Account 182.3, Other Regulatory Assets, with an offsetting entry to
Account 554, Maintenance of Miscellaneous Other Power Generation Plant. This deferral
will not include a carrying charge.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 16
25. Wildfire Mitigation Plan (“WMP”). In future iterations of the WMP Idaho
Power agrees to include a line that breaks down internal labor expenses for all WMP
programs and to extend the WMP forecast to five years for each version. The Company also
agrees to explore methods to reduce costs with communication and education regarding
wildfire and Public Safety Power Shutoffs.
D. Other General Provisions
26. The Parties agree that this Stipulation represents a compromise of the
positions of the Parties in this case. As provided in RP 272, other than any testimony
filed in support of the approval of this Stipulation, and except to the extent necessary for
a Party to explain before the Commission its own statements and positions with respect
to the Stipulation, all statements made and positions taken in negotiations relating to this
Stipulation shall be confidential and will not be admissible in evidence in this or any other
proceeding, unless all Parties to the negotiation agree to the contrary in writing.
27. The Parties submit this Stipulation to the Commission and recommend
approval in its entirety pursuant to RP 274. Parties shall support this Stipulation before
the Commission, and no Party shall appeal a Commission Order approving the Stipulation
without modification or condition. If this Stipulation is challenged by any person not a
party to the Stipulation, the Parties to this Stipulation 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 Stipulation. Notwithstanding this reservation of rights,
the Parties to this Stipulation agree that they will continue to support the Commission’s
adoption of the terms of this Stipulation.
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 17
28. If the Commission rejects any part or all of this Stipulation or imposes any
additional material conditions on approval of this Stipulation, each Party reserves the
right, upon written notice to the Commission and the other Parties to this proceeding,
within fourteen (14) days of the date of such action by the Commission, to withdraw from
this Stipulation. In such case, no Party shall be bound or prejudiced by the terms of this
Stipulation, and each Party shall be entitled to seek reconsideration of the Commission’s
Order, file testimony as it chooses, cross-examine witnesses, and do all other things
necessary to put on such case as it deems appropriate. In such case, the Parties
immediately will request the prompt reconvening of a prehearing conference for purposes
of establishing a procedural schedule for the completion of the case. The Parties agree
to cooperate in development of a schedule that concludes the proceeding on the earliest
possible date, taking into account the needs of the Parties in participating in hearings and
preparing briefs.
29. The Parties agree that this Stipulation represents a fair, just, and reasonable
compromise of the issues in this proceeding and that this Stipulation is in the public
interest.
30. No Party shall be bound, benefited, or prejudiced by any position asserted
in the negotiation of this Stipulation, except to the extent expressly stated herein, nor shall
this Stipulation be construed as a waiver of the rights of any Party unless such rights are
expressly waived herein. Except as otherwise expressly provided for herein, execution
of this Stipulation shall not be deemed to constitute an acknowledgment by any Party of
the validity or invalidity of any particular method, theory, or principle of regulation or cost
recovery. No Party shall be deemed to have agreed that any method, theory or principle
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 18
of regulation or cost recovery employed in arriving at this Stipulation is appropriate for
resolving any issues in any other proceeding in the future. No findings of fact or
conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
31. The obligations of the Parties under this Stipulation are subject to the
Commission’s approval of this Stipulation in accordance with its terms and conditions and
upon such approval being upheld on appeal, if any, by a court of competent jurisdiction.
32. This Stipulation may be executed in counterparts and each signed
counterpart shall constitute an original document.
DATED this 27th day of October 2023.
Idaho Power Company

By
Lisa D. Nordstrom
Attorney for Idaho Power Company

Idaho Public Utilities Commission Staff

By
Chris Burdin
Attorney for Commission Staff
Idaho Irrigation Pumpers Association, Inc.

By
Eric L. Olsen
Attorney for Idaho Irrigation Pumpers
Association, Inc.

Industrial Customers of Idaho Powe

By
Peter J. Richardson
Attorney for Industrial Customers
of Idaho Power

Micron Technology, Inc.

By
Austin Rueschhoff
Attorney for Micron Technology, Inc.

Federal Executive Agencies

By
Peter Meier
Attorney for Federal Executive
Agencies

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
STIPULATION AND SETTLEMENT - 19
Walmart, Inc.

By
Justina A. Caviglia
Attorney for Walmart, Inc.

Idaho Conservation League

By
Matthew Nykiel
Attorney for Idaho Conservation
League

IdaHydro

By
C. Tom Arkoosh
Attorney for IdaHydro

NW Energy Coalition

By
Diego Rivas
Attorney for NW Energy Coalition

City of Boise

By
Ed Jewell
Attorney for City of Boise
Clean Energy Opportunities for Idaho

By
Kelsey Jae
Attorney for Clean Energy
Opportunities for Idaho

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-23-11
STIPULATION AND SETTLEMENT
EXHIBIT 1
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Rate 2023 Test Year Final Final Final
Schedule Revenue Revenue Revenue Percent
Tariff Description No.w/ Transfer Adjustment Allocation Change Change
Residential Service 1,3,5 564,276,394$ 595,468,521$ 31,192,126$
Residential Service - On Site Gen 6 12,990,642 13,683,222 692,580$
Combined Residential 577,267,036 609,151,742 31,884,706$ 5.52%
Small General Service 7 17,713,519 18,690,670 977,151$
Small General Service - On Site Gen 8 48,033 51,921 3,889$
Combined Small General Service 17,761,552 18,742,592 981,040$ 5.52%
Large General Service - Prim. & Trans.9P, 9T 43,351,364 44,272,312 920,948$ 2.12%
Large General Service - Secondary 9S 268,689,371 274,397,356 5,707,985$ 2.12%
Dusk/Dawn Lighting 15 1,325,232 1,325,232 -$ 0.00%
Large Power Service 19S, 19P, 19T 153,080,729 157,333,066 4,252,337$ 2.78%
Irrigation Service 24 161,808,724 170,746,050 8,937,326$ 5.52%
Unmetered Service 40 1,305,019 1,307,805 2,786$ 0.21%
Municipal Street Lighting 41 3,742,273 3,742,273 -$ 0.00%
Traffic Control Lighting 42 198,268 209,219 10,951$ 5.52%
Micron 26 36,388,841 37,718,089 1,329,248$ 3.65%
Simplot 29 9,758,679 9,965,990 207,311$ 2.12%
DOE/INL 30 13,222,738 13,707,886 485,148$ 3.67%
Total Idaho Retail Sales (Excluding CEYW)1,287,899,827$ 1,342,619,613$ 54,719,786$ 4.25%
Exhibit No. 1 - Rate Spread
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Exhibit No. 1
Case No. IPC‐E‐23‐11
Settlement Stipulation
Page 1 of 1
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-23-11

STIPULATION AND SETTLEMENT

EXHIBIT 2

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service
Schedule 1 and Schedule 6
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 6,057,159 5.00$ 30,285,794$ 10.00$ 60,571,587$
2 Minimum Charge 72,347 2.00 144,694 3.00 217,041
3 Summer Energy (Jun-Aug)
4 First 800 kWh 879,383,006 0.086518$ 76,082,459$
5 801-2,000 kWh 440,951,703 0.104033 45,873,529
6 All Additional kWh 86,252,522 0.123585 10,659,518
7 Subtotal - Summer Energy 1,406,587,230 0.094282$ 132,615,505$
8 Non-Summer Energy (Sep-May)
9 First 800 kWh 2,579,932,201 0.080390$ 207,400,750$
10 801-2,000 kWh 1,101,608,616 0.088627 97,632,267
11 All Additional kWh 438,920,446 0.098154 43,081,797
12 Subtotal - Non-Summer Energy 4,120,461,263 0.084484$ 348,114,814$
13 Subtotal - Total Energy 5,527,048,493 480,730,319$
14 Summer Energy (Jun-Sep)
15 First 800 kWh 1,158,501,794 0.101082$ 117,103,678$
16 801-2,000 kWh 534,019,069 0.121546 64,907,882
17 All Additional kWh 99,239,843 0.144385 14,328,745
18 Subtotal - Summer Energy 1,791,760,706 0.109580$ 196,340,305$
19 Non-Summer Energy (Oct-May)
20 First 800 kWh 2,305,593,411 0.088958$ 205,100,979$
21 801-2,000 kWh 1,007,012,144 0.098073 98,760,702
22 All Additional kWh 422,682,232 0.108615 45,909,631
23 Subtotal - Non-Summer Energy 3,735,287,787 0.093640$ 349,771,311$
24 Subtotal - Total Energy 5,527,048,493 546,111,616$
25 Transfer Adjustment Revenue 63,972,859$
26 Total Adjusted Base Revenue 575,133,665$ 606,900,244$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 1 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service
Schedule 1
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 5,897,706 5.00$ 29,488,531$ 10.00$ 58,977,061$
2 Minimum Charge 70,865 2.00 141,730 3.00 212,595
3 Summer Energy (Jun-Aug)
4 First 800 kWh 861,147,615 0.086518$ 74,504,769$
5 801-2,000 kWh 433,910,571 0.104033 45,141,018
6 All Additional kWh 83,411,640 0.123585 10,308,428
7 Subtotal - Summer Energy 1,378,469,826 0.094274$ 129,954,215$
8 Non-Summer Energy (Sep-May)
9 First 800 kWh 2,525,398,940 0.080390$ 203,016,821$
10 801-2,000 kWh 1,077,473,224 0.088627 95,493,219
11 All Additional kWh 422,794,007 0.098154 41,498,923
12 Subtotal - Non-Summer Energy 4,025,666,171 0.084460$ 340,008,963$
13 Subtotal - Total Energy 5,404,135,997 469,963,178$
14 Summer Energy (Jun-Sep)
15 First 800 kWh 1,132,664,858 0.101082$ 114,492,029$
16 801-2,000 kWh 526,078,657 0.121546 63,942,756
17 All Additional kWh 97,206,864 0.144385 14,035,213
18 Subtotal - Summer Energy 1,755,950,379 0.109610$ 192,469,999$
19 Non-Summer Energy (Oct-May)
20 First 800 kWh 2,253,877,358 0.088958$ 200,500,422$
21 801-2,000 kWh 985,186,843 0.098073 96,620,229
22 All Additional kWh 409,121,417 0.108615 44,436,723
23 Subtotal - Non-Summer Energy 3,648,185,618 0.093624$ 341,557,374$
24 Subtotal - Total Energy 5,404,135,997 534,027,373$
25 Transfer Adjustment Revenue 62,549,585$
26 Total Adjusted Base Revenue 562,143,024$ 593,217,029$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 2 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service On-Site Generation
Schedule 6
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 159,453 5.00$ 797,263$ 10.00$ 1,594,526$
2 Minimum Charge 1,482 2.00 2,964 3.00 4,446
3 Summer Energy (Jun-Aug)
4 First 800 kWh 18,235,390 0.086518$ 1,577,690$
5 801-2,000 kWh 7,041,132 0.104033 732,510
6 All Additional kWh 2,840,881 0.123585 351,090
7 Subtotal - Summer Energy 28,117,404 0.094649$ 2,661,290$
8 Non-Summer Energy (Sep-May)
9 First 800 kWh 54,533,261 0.080390$ 4,383,929$
10 801-2,000 kWh 24,135,393 0.088627 2,139,047
11 All Additional kWh 16,126,439 0.098154 1,582,874
12 Subtotal - Non-Summer Energy 94,795,092 0.085509$ 8,105,851$
13 Subtotal - Total Energy 122,912,496 10,767,141$
14 Summer Energy (Jun-Sep)
15 First 800 kWh 25,836,936 0.101082$ 2,611,649$
16 801-2,000 kWh 7,940,411 0.121546 965,125
17 All Additional kWh 2,032,980 0.144385 293,532
18 Subtotal - Summer Energy 35,810,327 0.108078$ 3,870,306$
19 Non-Summer Energy (Oct-May)
20 First 800 kWh 51,716,052 0.088958$ 4,600,557$
21 801-2,000 kWh 21,825,301 0.098073 2,140,473
22 All Additional kWh 13,560,815 0.108615 1,472,908
23 Subtotal - Non-Summer Energy 87,102,169 0.094302$ 8,213,937$
24 Subtotal - Total Energy 122,912,496 12,084,243$
25 Transfer Adjustment Revenue 1,423,274$
26 Total Adjusted Base Revenue 12,990,642$ 13,683,215$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 3 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service
Schedule 1 and Schedule 6
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 6,057,159 5.00$ 30,285,794$ 15.00$ 90,857,381$
2 Minimum Charge 72,347 2.00 144,694 3.00 217,041
3 Summer Energy (Jun-Aug)
4 First 800 kWh 879,383,006 0.086518$ 76,082,459$
5 801-2,000 kWh 440,951,703 0.104033 45,873,529
6 All Additional kWh 86,252,522 0.123585 10,659,518
7 Subtotal - Summer Energy 1,406,587,230 0.094282$ 132,615,505$
8 Non-Summer Energy (Sep-May)
9 First 800 kWh 2,579,932,201 0.080390$ 207,400,750$
10 801-2,000 kWh 1,101,608,616 0.088627 97,632,267
11 All Additional kWh 438,920,446 0.098154 43,081,797
12 Subtotal - Non-Summer Energy 4,120,461,263 0.084484$ 348,114,814$
13 Subtotal - Total Energy 5,527,048,493 480,730,319$
14 Summer Energy (Jun-Sep)
15 First 800 kWh 1,158,501,794 0.095477$ 110,610,276$
16 801-2,000 kWh 534,019,069 0.114805 61,308,059
17 All Additional kWh 99,239,843 0.136386 13,534,925
18 Subtotal - Summer Energy 1,791,760,706 0.103503$ 185,453,260$
19 Non-Summer Energy (Oct-May)
20 First 800 kWh 2,305,593,411 0.084024$ 193,725,181$
21 801-2,000 kWh 1,007,012,144 0.092634 93,283,563
22 All Additional kWh 422,682,232 0.102592 43,363,816
23 Subtotal - Non-Summer Energy 3,735,287,787 0.088446$ 330,372,559$
24 Subtotal - Total Energy 5,527,048,493 515,825,820$
25 Transfer Adjustment Revenue 63,972,859$
26 Total Adjusted Base Revenue 575,133,665$ 606,900,241$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 4 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Master-Metered Mobile Home Park Residential Service
Schedule 3
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 225 5.00$ 1,124$ 10.00$ 2,248$
2 Energy Charge 4,476,086 0.087075$ 389,755 0.103844$ 464,815
3 Transfer Adjustment Revenue 51,737
4 Total Adjusted Base Revenue 442,616$ 467,063$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 5 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Master-Metered Mobile Home Park Residential Service
Schedule 3
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 225 5.00$ 1,124$ 15.00$ 3,372$
2 Energy Charge 4,476,086 0.087075$ 389,755 0.103593$ 463,691
3 Transfer Adjustment Revenue 51,737
4 Total Adjusted Base Revenue 442,616$ 467,063$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 6 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service - Time-of-Use
Schedule 5
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 11,836 5.00$ 59,179$ 10.00$ 118,357$
2 Minimum Charge 29 2.00 58 3.00 87
3 Summer Energy (Jun-Aug)
4 On-Peak 1,317,837 0.128910$ 169,882$
5 Off-Peak 2,932,059 0.073899 216,676
6 Subtotal - Summer Energy 4,249,896 0.090957$ 386,559$
7 Non-Summer Energy (Sep-May)
8 On-Peak 5,206,937 0.095159$ 495,487$
9 Off-Peak 7,490,517 0.073899 553,542
10 Subtotal - Non-Summer Energy 12,697,455 0.082617$ 1,049,029$
11 Subtotal - Total Energy 16,947,350 1,435,587$
12 Summer Energy (Jun-Sep)
13 On-Peak 999,802 0.246472$ 246,423$
14 Mid-Peak 794,685 0.123238 97,935
15 Off-Peak 3,615,751 0.061618 222,795
16 Subtotal - Summer Energy 5,410,238 0.104830$ 567,154$
17 Non-Summer Energy (Oct-May)
18 On-Peak 2,715,769 0.127787$ 347,040$
19 Off-Peak 8,821,344 0.085191 751,499
20 Subtotal - Non-Summer Energy 11,537,113 0.095218$ 1,098,539$
21 Subtotal - Total Energy 16,947,350 1,665,693$
22 Transfer Adjustment Revenue 195,931$
23 Total Adjusted Base Revenue 1,690,755$ 1,784,137$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 7 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Residential Service - Time-of-Use
Schedule 5
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 11,836 5.00$ 59,179$ 15.00$ 177,536$
2 Minimum Charge 29 2.00 58 3.00 87
3 Summer Energy (Jun-Aug)
4 On-Peak 1,317,837 0.128910$ 169,882$
5 Off-Peak 2,932,059 0.073899 216,676
6 Subtotal - Summer Energy 4,249,896 0.090957$ 386,559$
7 Non-Summer Energy (Sep-May)
8 On-Peak 5,206,937 0.095159$ 495,487$
9 Off-Peak 7,490,517 0.073899 553,542
10 Subtotal - Non-Summer Energy 12,697,455 0.082617$ 1,049,029$
11 Subtotal - Total Energy 16,947,350 1,435,587$
12 Summer Energy (Jun-Sep)
13 On-Peak 999,802 0.237716$ 237,669$
14 Mid-Peak 794,685 0.118854 94,451
15 Off-Peak 3,615,751 0.059429 214,880
16 Subtotal - Summer Energy 5,410,238 0.101105$ 547,001$
17 Non-Summer Energy (Oct-May)
18 On-Peak 2,715,769 0.123248$ 334,713$
19 Off-Peak 8,821,344 0.082165 724,806
20 Subtotal - Non-Summer Energy 11,537,113 0.091836$ 1,059,519$
21 Subtotal - Total Energy 16,947,350 1,606,520$
22 Transfer Adjustment Revenue 195,931$
23 Total Adjusted Base Revenue 1,690,755$ 1,784,142$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 8 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Small General Service
Schedule 7 and Schedule 8 Combined
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 365,860 5.00$ 1,829,301$ 25.00$ 9,146,505$
2 Minimum Charge 2,183 2.00 4,366 3.00 6,549
3 Summer Energy (Jun-Aug)
4 0 - 300 kWh 15,552,833 0.098633$ 1,534,023$
5 All Additional kWh 19,695,659 0.117472 2,313,688
6 Subtotal - Summer Energy 35,248,492 0.109160$ 3,847,711$
7 Non-Summer Energy (Sep-May)
8 0 - 300 kWh 48,683,072 0.098633$ 4,801,757$
9 All Additional kWh 54,724,304 0.103486 5,663,199
10 Subtotal - Non-Summer Energy 103,407,376 0.101201$ 10,464,957$
11 Subtotal - Total Energy 138,655,868 14,312,668$
12 Summer Energy (Jun-Sep)
13 0 - 300 kWh 20,489,851 0.067404$ 1,381,098$
14 All Additional kWh 25,224,107 0.077027 1,942,937
15 Subtotal - Summer Energy 45,713,958 0.072714$ 3,324,035$
16 Non-Summer Energy (Oct-May)
17 0 - 300 kWh 43,567,779 0.067404$ 2,936,643$
18 All Additional kWh 49,374,131 0.067421 3,328,853
19 Subtotal - Non-Summer Energy 92,941,910 0.067413$ 6,265,496$
20 Subtotal - Total Energy 138,655,868 9,589,531$
21 Transfer Adjustment Revenue 1,615,217$
22 Total Adjusted Base Revenue 17,761,552$ 18,742,585$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 9 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Small General Service
Schedule 7
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 364,810 5.00$ 1,824,051$ 25.00$ 9,120,255$
2 Minimum Charge 2,177 2.00 4,354 3.00 6,531
3 Summer Energy (Jun-Aug)
4 0 - 300 kWh 15,526,486 0.098633$ 1,531,424$
5 All Additional kWh 19,639,552 0.117472 2,307,097
6 Subtotal - Summer Energy 35,166,038 0.109154$ 3,838,521$
7 Non-Summer Energy (Sep-May)
8 0 - 300 kWh 48,565,776 0.098633$ 4,790,188$
9 All Additional kWh 54,553,347 0.103486 5,645,508
10 Subtotal - Non-Summer Energy 103,119,122 0.101200$ 10,435,696$
11 Subtotal - Total Energy 138,285,160 14,274,217$
12 Summer Energy (Jun-Sep)
13 0 - 300 kWh 20,448,718 0.067404$ 1,378,325$
14 All Additional kWh 25,155,159 0.077027 1,937,626
15 Subtotal - Summer Energy 45,603,878 0.072712$ 3,315,952$
16 Non-Summer Energy (Oct-May)
17 0 - 300 kWh 43,462,704 0.067404$ 2,929,560$
18 All Additional kWh 49,218,578 0.067421 3,318,366
19 Subtotal - Non-Summer Energy 92,681,282 0.067413$ 6,247,926$
20 Subtotal - Total Energy 138,285,160 9,563,878$
21 Transfer Adjustment Revenue 1,610,897$
22 Total Adjusted Base Revenue 17,713,519$ 18,690,664$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 10 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Small General Service On-Site Generation
Schedule 8
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 1,050 5.00$ 5,250$ 25.00$ 26,250$
2 Minimum Charge 6 2.00 12 3.00 18
3 Summer Energy (Jun-Aug)
4 0 - 300 kWh 26,347 0.098633$ 2,599$
5 All Additional kWh 56,107 0.117472 6,591
6 Subtotal - Summer Energy 82,454 0.111452$ 9,190$
7 Non-Summer Energy (Sep-May)
8 0 - 300 kWh 117,296 0.098633$ 11,569$
9 All Additional kWh 170,958 0.103486 17,692
10 Subtotal - Non-Summer Energy 288,254 0.101511$ 29,261$
11 Subtotal - Total Energy 370,708 38,451$
12 Summer Energy (Jun-Sep)
13 0 - 300 kWh 41,132 0.067404$ 2,772$
14 All Additional kWh 68,948 0.077027 5,311
15 Subtotal - Summer Energy 110,080 0.073431$ 8,083$
16 Non-Summer Energy (Oct-May)
17 0 - 300 kWh 105,075 0.067404$ 7,082$
18 All Additional kWh 155,553 0.067421 10,488
19 Subtotal - Non-Summer Energy 260,628 0.067414$ 17,570$
20 Subtotal - Total Energy 370,708 25,653$
21 Transfer Adjustment Revenue 4,320$
22 Total Adjusted Base Revenue 48,033$ 51,921$
END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 11 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large General Service
Schedule 9 Secondary Standard Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 453,162 16.00$ 7,250,592$ 25.00$ 11,329,050$
2 Minimum Charge 1,784 5.00 8,920 3.00 5,352
3 Basic Charge
4 Total Basic Charge (Current)8,516,555 1.03$ 8,772,052$
5 Total Basic Charge (Proposed)15,010,667 1.48$ 22,215,788$
6 Demand Charge (Current)
7 0-20 kW 5,349,195 -$ -$
8 Over 20 kW - Summer 1,562,250 6.06 9,467,238
9 Over 20 kW - Non-Summer 4,230,876 4.45 18,827,398
10 Total Demand 11,142,321 28,294,636$
11 Demand Charge (Proposed)
12 Summer kW 3,897,816 7.66$ 29,857,270$
13 Non-Summer kW 7,244,505 6.04 43,756,813
14 Total Demand 11,142,321 73,614,083$
15 Summer Energy (Current)
16 0-2,000 kWh 166,185,698 0.105250$ 17,491,045$
17 Over 2,000 kWh 705,756,622 0.048716 34,381,640
18 Subtotal - Summer Energy 871,942,320 0.059491$ 51,872,684$
19 Non-Summer Energy (Current)
20 0-2,000 kWh 514,806,364 0.094742$ 48,773,785$
21 Over 2,000 kWh 1,934,795,934 0.044196 85,510,241
22 Subtotal - Non-Summer Energy 2,449,602,298 0.054819$ 134,284,026$
23 Subtotal - Total Energy 3,321,544,618 186,156,710$
24 Summer Energy (Jun-Sep)
25 All kWh 1,143,297,617 0.051548$ 58,934,706$
26 Non-Summer Energy (Oct-May)
27 All kWh 2,178,247,001 0.049718$ 108,298,084$
28 Subtotal - Total Energy 3,321,544,618 167,232,790$
29 Transfer Adjustment Revenue 38,206,461$
30 Total Adjusted Base Revenue 268,689,371$ 274,397,062$
END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 12 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large General Service
Schedule 9 Secondary TOU Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 453,162 16.00$ 7,250,592$ 25.00$ 11,329,050$
2 Minimum Charge 1,784 5.00 8,920 3.00 5,352
3 Basic Charge
4 Total Basic Charge (Current)8,516,555 1.03$ 8,772,052$
5 Total Basic Charge (Proposed)15,010,667 1.48$ 22,215,788$
6 Demand Charge (Current)
7 0-20 kW 5,349,195 -$ -$
8 Over 20 kW - Summer 1,562,250 6.06 9,467,238
9 Over 20 kW - Non-Summer 4,230,876 4.45 18,827,398
10 Total Demand 11,142,321 28,294,636$
11 Demand Charge (Proposed)
12 Summer kW 3,897,816 7.66$ 29,857,270$
13 Non-Summer kW 7,244,505 6.04 43,756,813
14 Total Demand 11,142,321 73,614,083$
15 Summer Energy (Current)
16 0-2,000 kWh 166,185,698 0.105250$ 17,491,045$
17 Over 2,000 kWh 705,756,622 0.048716 34,381,640
18 Subtotal - Summer Energy 871,942,320 0.059491$ 51,872,684$
19 Non-Summer Energy (Current)
20 0-2,000 kWh 514,806,364 0.094742$ 48,773,785$
21 Over 2,000 kWh 1,934,795,934 0.044196 85,510,241
22 Subtotal - Non-Summer Energy 2,449,602,298 0.054819$ 134,284,026$
23 Subtotal - Total Energy 3,321,544,618 186,156,710$
24 Summer Energy (Jun-Sep)
25 On-Peak 158,721,787 0.055149$ 8,753,348$
26 Mid-Peak 229,027,384 0.055149 12,630,631
27 Off-Peak 755,548,446 0.049700 37,550,758
28 Subtotal - Summer Energy 1,143,297,617 0.051548$ 58,934,737$
29 Non-Summer Energy (Oct-May)
30 On-Peak 482,938,805 0.052572$ 25,389,059$
31 Mid-Peak 506,997,039 0.050218 25,460,377
32 Off-Peak 1,188,311,158 0.048345 57,448,903
33 Subtotal - Non-Summer Energy 2,178,247,001 0.049718$ 108,298,339$
34 Subtotal - Total Energy 3,321,544,618 167,233,076$
35 Transfer Adjustment Revenue 38,206,461$
35 Total Adjusted Base Revenue 268,689,371$ 274,397,348$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 13 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large General Service
Schedule 9 Primary Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 3,362 285.00$ 958,142$ 340.00$ 1,143,046$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge 1,935,320 1.30$ 2,515,916$ 1.73$ 3,348,103$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)421,737 5.16$ 2,176,164$
7 Non-Summer (Sep-May)1,129,739 4.52 5,106,419
8 Total Demand 1,551,476 7,282,583$
9 On-Peak Summer Demand (Jun-Aug)394,562 0.97$ 382,725$
10 Demand Charge (Proposed Seasons)
11 Summer (Jun-Sep)562,598 7.89$ 4,438,896$
12 Non-Summer (Oct-May)988,878 7.48 7,396,808
13 Total Demand 1,551,476 11,835,704$
14 On-Peak Summer Demand (Jun-Sep)525,669 1.49$ 783,247$
15 Summer Energy (Jun-Aug)
16 On-Peak 45,450,558 0.049454$ 2,247,712$
17 Mid-Peak 70,944,613 0.045633 3,237,416
18 Off-Peak 46,864,805 0.043133 2,021,420
19 Subtotal - Summer Energy 163,259,977 0.045979$ 7,506,547$
20 Non-Summer Energy (Sep-May)
21 Mid-Peak 266,940,199 0.040920$ 10,923,193$
22 Off-Peak 167,941,864 0.039546 6,641,429
23 Subtotal - Non-Summer Energy 434,882,062 0.040389$ 17,564,622$
24 Subtotal - Total Energy 598,142,039 25,071,169$
25 Summer Energy (Jun-Sep)
26 On-Peak 29,601,623 0.050975$ 1,508,943$
27 Mid-Peak 41,637,317 0.050975 2,122,462
28 Off-Peak 143,727,301 0.045704 6,568,913
29 Subtotal - Summer Energy 214,966,240 0.047451$ 10,200,317$
30 Non-Summer Energy (Oct-May)
31 On-Peak 85,400,026 0.046295$ 3,953,594$
32 Mid-Peak 87,831,834 0.044020 3,866,357
33 Off-Peak 209,943,940 0.042196 8,858,794
34 Subtotal - Non-Summer Energy 383,175,799 0.043528$ 16,678,746$
35 Subtotal - Total Energy 598,142,039 26,879,063$
36 Transfer Adjustment Revenue 6,863,718$
37 Total Adjusted Base Revenue 43,074,252$ 43,989,164$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 14 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large General Service
Schedule 9 Transmission Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 48 285.00$ 13,680$ 340.00$ 16,320$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge 17,008 0.69$ 11,736$ 1.03$ 17,519$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)3,210 4.84$ 15,537$
7 Non-Summer (Sep-May)10,676 4.36 46,546
8 Total Demand 13,886 62,083$
9 On-Peak Summer Demand (Jun-Aug)2,749 0.97$ 2,667$
10 Demand Charge (Proposed Seasons)
11 Summer (Jun-Sep)4,400 6.95$ 30,577$
12 Non-Summer (Oct-May)9,486 6.09 57,772
13 Total Demand 13,886 88,349$
14 On-Peak Summer Demand (Jun-Sep)3,767 1.49$ 5,613$
15 Summer Energy (Jun-Aug)
16 On-Peak 193,515 0.048664$ 9,417$
17 Mid-Peak 350,627 0.045000 15,778
18 Off-Peak 236,395 0.042585 10,067
19 Subtotal - Summer Energy 780,537 0.045177$ 35,262$
20 Non-Summer Energy (Sep-May)
21 Mid-Peak 1,661,772 0.040408$ 67,149$
22 Off-Peak 1,114,834 0.039155 43,651
23 Subtotal - Non-Summer Energy 2,776,606 0.039905$ 110,800$
24 Subtotal - Total Energy 3,557,143 146,063$
25 Summer Energy (Jun-Sep)
26 On-Peak 110,660 0.050239$ 5,559$
27 Mid-Peak 169,020 0.050239 8,491
28 Off-Peak 760,683 0.044908 34,161
29 Subtotal - Summer Energy 1,040,363 0.046341$ 48,212$
30 Non-Summer Energy (Oct-May)
31 On-Peak 542,469 0.045313$ 24,581$
32 Mid-Peak 572,351 0.043036 24,632
33 Off-Peak 1,401,959 0.041210 57,775
34 Subtotal - Non-Summer Energy 2,516,780 0.042510$ 106,987$
35 Subtotal - Total Energy 3,557,143 155,199$
36 Transfer Adjustment Revenue 40,883$
37 Total Adjusted Base Revenue 277,112$ 282,999$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 15 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power CompanyState of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Dusk-to-Dawn Customer Lighting
Schedule 15
1 2 3 4 5 6 7 8 9
Curren Curren Pro osed Pro osedLine Annua kW Base Base Pro osed Annua kW Base Base
No Description Lamps Use Rate Revenue Structure Lamps Use Rate Revenue
01 Lamps Area Lightin2 100-Watt Sodium Vapor (A 89,714 0 9.63$ 863,946$ 40 Watt Max 89,714 0 9.45$ 847,797$ 3 200-Watt Sodium Vapor (A 9,459 0 11.50$ 108,777$ 85 Watt Max 9,459 0 11.50$ 108,777$ 4 400-Watt Sodium Vapor (A 1,801 0 15.57$ 28,035$ 200 Watt Max 1,801 0 16.61$ 29,907$ 5 200-Watt Sodium Vapor (D 9,599 0 13.78$ 132,280$
6 400-Watt Sodium Vapor (D 5,387 0 16.24$ 87,493$ Flood Lightin7 400-Watt Metal Halide (D 1,164 0 14.91$ 17,356$ 85 Watt Max 9,599 0 18.76$ 180,085$ 8 1000-Watt Metal Halide(D 956 0 23.71$ 22,665$ 150 Watt Max 6,552 0 20.67$ 135,421$ 9 0 300 Watt Max 956 0 24.31$ 23,239$
10 Total 118,080 5,267,423 1,260,552$ Total 118,080 5,267,423 1,325,226$
11 Minimum Charg 434 3.00$ 1,301$ Minimum Charg 434 -$ -$
12 Transfer Adjustmen 63,379$ Transfer Adjustmen -$
ota uste ase evenu ,, ota uste ase evenu ,,
 END § § § § § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 16 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large Power Service
Schedule 19 Secondary Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 12 39.00$ 468$ 85.00$ 1,020$
2 Minimum Charge - 5.00 - 5.00 -
3 Basic Charge
4 Total Basic Charge 14,167 0.93$ 13,176$ 1.90$ 26,918$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)3,233 5.99$ 19,365$
7 Non-Summer (Sep-May)10,109 4.30 43,467
8 Total Demand 13,342 62,832$
9 On-Peak Summer Demand (Jun-Aug)2,591 1.03$ 2,669$
10 Demand Charge (Proposed Seasons)
11 Summer (Jun-Sep)4,291 9.90$ 42,477$
12 Non-Summer (Oct-May)9,051 7.97 72,136
13 Total Demand 13,342 114,613$
14 On-Peak Summer Demand (Jun-Sep)3,439 1.71$ 5,880$
15 Summer Energy (Jun-Aug)
16 On-Peak 423,806 0.064456$ 27,317$
17 Mid-Peak 563,279 0.051034 28,746
18 Off-Peak 664,973 0.045292 30,118
19 Subtotal - Summer Energy 1,652,057 0.052166$ 86,181$
20 Non-Summer Energy (Sep-May)
21 Mid-Peak 2,894,106 0.047466$ 137,372$
22 Off-Peak 1,988,464 0.042171 83,856
23 Subtotal - Non-Summer Energy 4,882,571 0.045310$ 221,227$
24 Subtotal - Total Energy 6,534,628 307,408$
25 Summer Energy (Jun-Sep)
26 On-Peak 324,610 0.056450$ 18,324$
27 Mid-Peak 418,903 0.056450 23,647
28 Off-Peak 1,459,219 0.051197 74,708
29 Subtotal - Summer Energy 2,202,732 0.052970$ 116,679$
30 Non-Summer Energy (Oct-May)
31 On-Peak 937,724 0.051110$ 47,927$
32 Mid-Peak 965,486 0.048829 47,144
33 Off-Peak 2,428,686 0.047000 114,148
34 Subtotal - Non-Summer Energy 4,331,896 0.048297$ 209,219$
35 Subtotal - Total Energy 6,534,628 325,898$
36 Transfer Adjustment Revenue 74,957$
37 Total Adjusted Base Revenue 461,510$ 474,329$
END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 17 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large Power Service
Schedule 19 Primary Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 1,356 299.00$ 405,444$ 415.00$ 562,740$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge 5,241,211 1.28$ 6,708,750$ 2.09$ 10,954,131$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)1,200,164 6.12$ 7,345,004$
7 Non-Summer (Sep-May)3,433,952 4.54 15,590,143
8 Total Demand 4,634,116 22,935,147$
9 On-Peak Summer Demand (Jun-Aug)1,153,172 0.97$ 1,118,577$
10 Demand Charge (Proposed Seasons)
11 Summer (Jun-Sep)1,600,720 9.47$ 15,158,818$
12 Non-Summer (Oct-May)3,033,396 8.14 24,691,846
13 Total Demand 4,634,116 39,850,663$
14 On-Peak Summer Demand (Jun-Sep)1,537,925 1.50$ 2,306,887$
15 Summer Energy (Jun-Aug)
16 On-Peak 155,742,275 0.053049$ 8,261,972$
17 Mid-Peak 258,777,524 0.042185 10,916,530
18 Off-Peak 192,288,068 0.037639 7,237,531
19 Subtotal - Summer Energy 606,807,867 0.043533$ 26,416,032$
20 Non-Summer Energy (Sep-May)
21 Mid-Peak 1,014,622,007 0.039765$ 40,346,444$
22 Off-Peak 725,865,453 0.035550 25,804,517
23 Subtotal - Non-Summer Energy 1,740,487,460 0.038007$ 66,150,961$
24 Subtotal - Total Energy 2,347,295,327 92,566,993$
25 Summer Energy (Jun-Sep)
26 On-Peak 115,731,721 0.049253$ 5,700,134$
27 Mid-Peak 149,838,340 0.049253 7,379,988
28 Off-Peak 535,937,021 0.043995 23,578,549
29 Subtotal - Summer Energy 801,507,082 0.045737$ 36,658,671$
30 Non-Summer Energy (Oct-May)
31 On-Peak 334,235,604 0.044526$ 14,882,175$
32 Mid-Peak 337,433,892 0.042244 14,254,557
33 Off-Peak 874,118,749 0.040414 35,326,635
34 Subtotal - Non-Summer Energy 1,545,788,245 0.041703$ 64,463,367$
35 Subtotal - Total Energy 2,347,295,327 101,122,038$
36 Transfer Adjustment Revenue 26,878,189$
37 Total Adjusted Base Revenue 150,613,100$ 154,796,460$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 18 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Large Power Service
Schedule 19 Transmission Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge 24 299.00$ 7,176$ 415.00$ 9,960$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge 60,014 0.71$ 42,610$ 1.76$ 105,624$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)15,188 5.93$ 90,063$
7 Non-Summer (Sep-May)43,455 4.41 191,638
8 Total Demand 58,643 281,700$
9 On-Peak Summer Demand (Jun-Aug)14,437 0.97$ 14,004$
10 Demand Charge (Proposed Seasons)
11 Summer (Jun-Sep)20,063 9.61$ 192,808$
12 Non-Summer (Oct-May)38,580 8.27 319,054
13 Total Demand 58,643 511,861$
14 On-Peak Summer Demand (Jun-Sep)19,071 1.50$ 28,606$
15 Summer Energy (Jun-Aug)
16 On-Peak 2,000,915 0.052447$ 104,942$
17 Mid-Peak 3,704,369 0.041889 155,172
18 Off-Peak 2,838,258 0.037394 106,134
19 Subtotal - Summer Energy 8,543,543 0.042868$ 366,248$
20 Non-Summer Energy (Sep-May)
21 Mid-Peak 13,775,429 0.039577$ 545,190$
22 Off-Peak 10,546,708 0.035383 373,174
23 Subtotal - Non-Summer Energy 24,322,137 0.037758$ 918,364$
24 Subtotal - Total Energy 32,865,680 1,284,612$
25 Summer Energy (Jun-Sep)
26 On-Peak 1,516,856 0.049086$ 74,456$
27 Mid-Peak 1,908,973 0.049086 93,704
28 Off-Peak 7,883,515 0.043799 345,290
29 Subtotal - Summer Energy 11,309,344 0.045401$ 513,450$
30 Non-Summer Energy (Oct-May)
31 On-Peak 4,606,525 0.044239$ 203,788$
32 Mid-Peak 4,608,196 0.041956 193,341
33 Off-Peak 12,341,615 0.040125 495,207
34 Subtotal - Non-Summer Energy 21,556,336 0.041396$ 892,337$
35 Subtotal - Total Energy 32,865,680 1,405,787$
36 Transfer Adjustment Revenue 376,017$
37 Total Adjusted Base Revenue 2,006,119$ 2,061,839$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 19 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Speculative High-Density Load
Schedule 20 Large General Service - Primary
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge - 285.00$ -$ 340.00$ -$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge - 1.30$ -$ 1.73$ -$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)- 5.41$ -$
7 Non-Summer (Sep-May)-4.77 -
8 Total Demand - -$
9 Demand Charge (Proposed Seasons)
10 Summer (Jun-Sep)- 8.39$ -$
11 Non-Summer (Oct-May)-7.98 -
12 Total Demand - -$
13 Summer Energy (Jun-Aug)
14 On-Peak - 0.069385$ -$
15 Mid-Peak - 0.058574 -
16 Off-Peak - 0.050354 -
17 Subtotal - Summer Energy - -$
18 Non-Summer Energy (Sep-May)
19 Mid-Peak - 0.049881$ -$
20 Off-Peak -0.044827 -
21 Subtotal - Non-Summer Energy - -$
22 Subtotal - Total Energy - -$
23 Summer Energy (Jun-Sep)
24 On-Peak - 0.088770$ -$
25 Mid-Peak - 0.115970 -
26 Off-Peak -0.065765 -
27 Subtotal - Summer Energy - -$
28 Non-Summer Energy (Oct-May)
29 On-Peak - 0.064611$ -$
30 Mid-Peak - 0.082028 -
31 Off-Peak -0.069063 -
32 Subtotal - Non-Summer Energy - -$
33 Subtotal - Total Energy - -$
34 Total Adjusted Base Revenue -$ -$
35 Interruption Compensation
36 per killowatt of reduction per event hour 0.0734$ 0.0333$
END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 20 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Speculative High-Density Load
Schedule 20 Large General Service - Transmission
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge - 285.00$ -$ 340.00$ -$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge - 0.69$ -$ 1.03$ -$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)- 5.09$ -$
7 Non-Summer (Sep-May)- 4.61 -
8 Total Demand - -$
9 Demand Charge (Proposed Seasons)
10 Summer (Jun-Sep)- 7.45$ -$
11 Non-Summer (Oct-May)- 6.59 -
12 Total Demand - -$
13 Summer Energy (Jun-Aug)
14 On-Peak - 0.068595$ -$
15 Mid-Peak - 0.057941 -
16 Off-Peak - 0.049806 -
17 Subtotal - Summer Energy - -$
18 Non-Summer Energy (Sep-May)
19 Mid-Peak - 0.049369$ -$
20 Off-Peak - 0.044436 -
21 Subtotal - Non-Summer Energy - -$
22 Subtotal - Total Energy - -$
23 Summer Energy (Jun-Sep)
24 On-Peak - 0.088034$ -$
25 Mid-Peak - 0.115234 -
26 Off-Peak - 0.064969 -
27 Subtotal - Summer Energy - -$
28 Non-Summer Energy (Oct-May)
29 On-Peak - 0.063629$ -$
30 Mid-Peak - 0.081044 -
31 Off-Peak - 0.068077 -
32 Subtotal - Non-Summer Energy - -$
33 Subtotal - Total Energy - -$
34 Total Adjusted Base Revenue -$ -$
35 Interruption Compensation
36 per killowatt of reduction per event hour 0.0734$ 0.0333$
 END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 21 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Speculative High-Density Load
Schedule 20 Large Power Service - Primary
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge - 299.00$ -$ 415.00$ -$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge - 1.28$ -$ 2.09$ -$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)- 6.36$ -$
7 Non-Summer (Sep-May)- 4.78 -
8 Total Demand - -$
9 Demand Charge (Proposed Seasons)
10 Summer (Jun-Sep)- 9.97$ -$
11 Non-Summer (Oct-May)- 8.64 -
12 Total Demand - -$
13 Summer Energy (Jun-Aug)
14 On-Peak - 0.072663$ -$
15 Mid-Peak - 0.054809 -
16 Off-Peak - 0.044543 -
17 Subtotal - Summer Energy - -$
18 Non-Summer Energy (Sep-May)
19 Mid-Peak - 0.048409$ -$
20 Off-Peak - 0.040514 -
21 Subtotal - Non-Summer Energy - -$
22 Subtotal - Total Energy - -$
23 Summer Energy (Jun-Sep)
24 On-Peak - 0.086996$ -$
25 Mid-Peak - 0.114196 -
26 Off-Peak - 0.064004 -
27 Subtotal - Summer Energy - -$
28 Non-Summer Energy (Oct-May)
29 On-Peak - 0.062790$ -$
30 Mid-Peak - 0.080200 -
31 Off-Peak - 0.067229 -
32 Subtotal - Non-Summer Energy - -$
33 Subtotal - Total Energy - -$
34 Total Adjusted Base Revenue -$ -$
35 Interruption Compensation
36 per killowatt of reduction per event hour 0.0835$ 0.0382$
 END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 22 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Speculative High-Density Load
Schedule 20 Large Power Service - Transmission
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Service Charge - 299.00$ -$ 415.00$ -$
2 Minimum Charge - 10.00 - 50.00 -
3 Basic Charge
4 Total Basic Charge - 0.71$ -$ 1.76$ -$
5 Demand Charge (Current Seasons)
6 Summer (Jun-Aug)- 6.17$ -$
7 Non-Summer (Sep-May)- 4.65 -
8 Total Demand - -$
9 Demand Charge (Proposed Seasons)
10 Summer (Jun-Sep)- 10.11$ -$
11 Non-Summer (Oct-May)- 8.77 -
12 Total Demand - -$
13 Summer Energy (Jun-Aug)
14 On-Peak - 0.072061$ -$
15 Mid-Peak - 0.054513 -
16 Off-Peak - 0.044298 -
17 Subtotal - Summer Energy - -$
18 Non-Summer Energy (Sep-May)
19 Mid-Peak - 0.048221$ -$
20 Off-Peak - 0.040347 -
21 Subtotal - Non-Summer Energy - -$
22 Subtotal - Total Energy - -$
23 Summer Energy (Jun-Sep)
24 On-Peak - 0.086829$ -$
25 Mid-Peak - 0.114029 -
26 Off-Peak - 0.063808 -
27 Subtotal - Summer Energy - -$
28 Non-Summer Energy (Oct-May)
29 On-Peak - 0.062503$ -$
30 Mid-Peak - 0.079912 -
31 Off-Peak - 0.066940 -
32 Subtotal - Non-Summer Energy - -$
33 Subtotal - Total Energy - -$
34 Total Adjusted Base Revenue -$ -$
35 Interruption Compensation
36 per killowatt of reduction per event hour 0.0835$ 0.0382$
 END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 23 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Agricultural Irrigation Service
Schedule 24 Secondary Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Bills-In Season 77,670 22.00$ 1,708,747$ 30.00$ 2,330,109$
2 Bills-Out Season 152,477 3.50 533,668 6.00 914,859
3 Minimum Charge 379 1.50 568 3.00 1,136
4 Total Service Charge 230,525 2,242,982$ 3,246,104$
5 Demand Charge
6 Total In-Season 4,065,427 7.06$ 28,701,912$ 14.06$ 57,159,898$
7 Total Out-Season - - - - -$
8 Total Demand 4,065,427 28,701,912$ 57,159,898$
9 In-Season Energy (Current)
10 First 164 kWh per kW 610,778,359 0.058436$ 35,691,444$
11 All Other kWh In-Season 897,748,435 0.055483 49,809,776
12 Subtotal - In-Season Energy 1,508,526,794 0.056679$ 85,501,221$
13 Out-Season Energy (Current)
14 All kWh 355,995,978 0.067084$ 23,881,634$
15 Subtotal - Total Energy 1,864,522,772 109,382,855$
16 In-Season Energy (Proposed)
17 All kWh 1,508,526,794 0.057265$ 86,385,787$
18 Out-Season Energy (Proposed)
19 All kWh 355,995,978 0.067288$ 23,954,257$
20 Subtotal - Total Energy 1,864,522,772 110,340,044$
21 Transfer Adjustment Revenue 21,480,975$
22 Total Adjusted Base Revenue 161,808,724$ 170,746,046$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 24 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Agricultural Irrigation Service
Schedule 24 Transmission Service
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No.Description Units Rate Revenue Rate Revenue
1 Bills-In Season - 299.00$ -$ 415.00$ -$
2 Bills-Out Season - 3.50 - 6.00 -
3 Total Service Charge - -$ -$
4 Demand Charge
5 Total In-Season - 6.66$ -$ 13.27$ -$
6 Total Out-Season - - - - -$
7 Total Demand - -$ -$
8 In-Season Energy (Current)
9 First 164 kWh per kW - 0.055978$ -$
10 All Other kWh In-Season - 0.053233 -
11 Subtotal - In-Season Energy - -$ -$
12 Out-Season Energy (Current)
13 All kWh - 0.064032$ -$
14 Subtotal - Total Energy - -$
15 In-Season Energy (Proposed)
16 All kWh - 0.054849$ -$
17 Out-Season Energy (Proposed)
18 All kWh - 0.064215$ -$
19 Subtotal - Total Energy - -$
20 Total Adjusted Base Revenue -$ -$
 END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 25 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Micron
Schedule 26
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective Revenue Percent
No.Description Units Rate Revenue Rate Revenue Difference Change
1 Contract Demand ($/kW)918,000 1.67$ 1,533,060$ 3.11$ 2,854,980$ 1,321,920$ 86.23%
2 Billed kW ($/kW)1,017,744 10.98$ 11,174,829 16.60$ 16,889,540 5,714,711 51.14%
3 Excess Demand kW ($/kW - 0.291$ - 1.244$ - - 0.00%
4 Embedded Energy Fixed Cost Charge ($/kWh) 101,867,460 0.002632$ 268,115 -$ - (268,115) -100.00%
5 Billed kWh ($/kWh)591,344,540 0.028150$ 16,646,349 0.030394$ 17,973,569 1,327,220 7.97%
6 Transfer Adjustment 6,766,488 -
7 Subtotal 36,388,841$ 37,718,089$ 1,329,248$ 3.65%
 END § § § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 26 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Simplot
Schedule 29
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective Revenue Percent
No.Description Units Rate Revenue Rate Revenue Difference Change
1 Contract Demand ($/kW)300,000 2.31$ 693,000$ 3.11$ 933,000$ 240,000$ 34.63%
1 Billed kW ($/kW)267,258 7.88$ 2,105,993 14.23$ 3,802,731 1,696,738 80.57%
2 Excess Demand kW ($/kW - 0.292$ - 1.244$ - -
3 Billed kWh ($/kWh)175,000,001 0.028345$ 4,960,375 0.029887$ 5,230,259 269,884 5.44%
4 Transfer Adjustment 1,999,311 -(1,999,311)
5 Subtotal 9,758,679$ 9,965,990$ 207,311$ 2.12%
END § §§§§§§END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 27 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Department of Energy
Schedule 30
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective Revenue Percent
No.Description Units Rate Revenue Rate Revenue Difference Change
1 Contract Demand ($/kW)- -$ -$ -$ -$ -$
2 Billed kW ($/kW)422,686 8.50$ 3,592,831 9.75$ 4,121,189 528,358 14.71%
3 Excess Demand kW ($/kW - -$ - -$ - -
4 Billed kWh ($/kWh)234,100,000 0.029709$ 6,954,877 0.040951$ 9,586,697 2,631,821 37.84%
5 Transfer Adjustment 2,675,030 - (2,675,030)
6 Subtotal 13,222,738$ 13,707,886$ 485,148$ 3.67%
 END § §§§§§§END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 28 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Simplot Caldwell
Schedule 32
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective Revenue Percent
No.Description Units Rate Revenue Rate Revenue Difference Change
1 Summer Contract Demand ($/kW)88,000 1.78$ 156,640$ 3.11$ 273,680$ 117,040$ 74.72%
2 Non-Summer Contract Demand ($/kW)156,000 1.78$ 277,680$ 3.11$ 485,160$ 207,480$ 74.72%
3 Summer Billed kW ($/kW)87,371 14.87$ 1,299,213 18.49$ 1,615,582 316,369$ 24.35%
4 Non-Summer Billed kW ($/kW)153,465 8.65$ 1,327,469 15.28$ 2,344,538 1,017,068$ 76.62%
5 Summer Excess Demand kW ($/kW)- 0.298$ - 1.244$ - -$
6 Non-Summer Excess Demand kW ($/kW)- 0.298$ - 1.244$ - -$
7 Summer Energy Charge ($/kWh)56,000,000 0.031252$ 1,750,112 0.028675$ 1,605,785 (144,327)$ -8.25%
8 Non-Summer Energy Charge ($/kWh 106,000,000 0.030664$ 3,250,384 0.030975$ 3,283,330 32,946$ 1.01%
9 Transfer Adjustment 1,848,876 - (1,848,876)$ -100.00%
10 Subtotal 9,910,375$ 9,608,075$ (302,300)$ -3.05%
 END § § § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 29 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Brisbie LLC - Block 2 Billing Demand
Schedule 33
Line
No.
1 Annual Cost ($)9,139,072$
2 Proposed 19T Revenue (6,245,241)$
3 Remaining Cost for Block 2 capacity 2,893,830$
4 Contract Demand ($/kW)($3.11)
5 Contract Demand Billing Determinant (kW)120,000
6 less Contract Demand recovery (373,200)$
7 Block 2 Billed Demand Capacity Cost 2,520,630$
8 Block 2 Demand Billing Determinant (kW)120,000
9 Billed Demand Charge ($/kW)21.01$
 END § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 30 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Lamb Weston - Block 2 Billing Demand
Schedule 34
Line
No.
1 Annual Cost ($)11,624,287$
2 Proposed 19P Revenue (8,503,003)$
3 Remaining Cost for Block 2 capacity 3,121,284$
4 Contract Demand ($/kW)$3.11
5 Contract Demand Billing Determinant (kW)144,000
6 less Contract Demand recovery (447,840)$
7 Block 2 Billed Demand Capacity Cost 2,673,444$
8 Block 2 Demand Billing Determinant (kW)117,000
9 Billed Demand Charge ($/kW)22.85$
 END § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 31 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Non-Metered General Service
Schedule 40
(1) (2) (3) (4) (5)
Current Current Proposed Proposed
Line Base Base Base Base
No Description Use Rate Revenue Rate Revenue
0
1 Number of Bills 19,956.0 -$ -$ -$ -$
2 Minimum Charge 846.8 1.50 1,270 2.00 1,694
3 Total Energy 13,925,301 0.08207$ 1,142,849$ 0.09377$ 1,305,775$
4 Intermittent Usage 168 1.00$ 168$ 2.00$ 336$
5 Transfer Adjustment 160,732$ -$
6 Total Adjusted Base Revenue 1,305,019$ 1,307,805$
 END §§ § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 32 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
(1 2 3 4CurrenProoseLineCurrenBase Pro ose BaseNoDescriptionUseRevenueUseRevenue
01 A - Company-Owned, Non-Metered, Maintenanc 4,153,143 2,359,648$ 4,153,143 2,416,621$ 2 B - Customer-Owned, Non-Metered, Maintenanc 2,214,987 149,735$ 0 -$ 3 BM - Customer-Owned, Metered, Maintenanc 78,103 4,750$ 0 -$ 4 C - Customer-Owned, Non-Metered, No Maintenanc 10,704,238 560,902$ 12,919,225 818,950$ 5 CM - Customer-Owned, Metered, No Maintenanc 6,609,543 388,286$ 6,687,646 506,701$
6 Total Bills 35,760 35,7607 Total kW 23,760,014 23,760,014
8 Transfer Adjustmen 278,951$ -$
9 Total Adjusted Base Revenu 3,742,273 3,742,272
Street Lighting Service
Schedule 41
Summar
Settlement StipulationIPC-E-23-11
Idaho Power Com an
State of IdahoCalculation of Proposed Rates
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 33 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
(1 2 3 4 5 6 7CurrenCurrenProoseProoseLineAnnual Base Base Pro ose Annual Base BaseNoDescriptionLampsRateRevenueStructureLampsRateRevenue
01 Sodium Vapor / LE LED2 70-Watt / 40-Watt Max 431 11.55$ 4,978$ 40-Watt Max 180,477 11.48$ 2,071,872$ 3 100-Watt / 40-Watt Max 180,046 11.01$ 1,982,302$ 85-Watt Max 20,137 13.38$ 269,436$ 4 200-Watt / 85-Watt Max 20,137 14.75$ 297,024$ 140-Watt Max 2,799 15.34$ 42,937$ 5 250-Watt / 140-Watt Max 2,799 16.05$ 44,924$ 200-Watt Max 1,486 19.06$ 28,319$ 6 400-Watt / 200-Watt Max 1,486 18.30$ 27,190$ Total LED 204,899 2,412,564$ 7 Total Sodium Vapor / LE 204,899 2,356,419$
8 Non-Metered - Variable Energy Us 43,270 0.07464$ 3,230$ 43,270 0.09377$ 4,057$
9 A - Company-Owned, Non-Metered, Maintenanc 2,359,648$ 2,416,621$
(1) (2) (3) (4) (5) (6) (7)Current Current Proposed ProposedLine Annual Base Base Proposed Annual Base Base
No Description Lamps Rate Revenue Structure Lamps Rate Revenue
0
1 70-Watt 0 3.11$ -$ N/A 0 -$ -$
2 100-Watt 23,799 3.48$ 82,821$ N/A 0 -$ -$
3 200-Watt 1,226 5.03$ 6,167$ N/A 0 -$ -$
4 250-Watt 8,039 6.20$ 49,842$ N/A 0 -$ -$
5 400-Watt 1,245 8.76$ 10,906$ N/A 0 -$ -$
6 Total Sodium Vapor 34,309 149,735$ 0 -$
7 Non-Metered - Variable Energy Use 0 0.07464$ -$ N/A 0 -$ -$
8 B - Customer-Owned, Non-Metered, Maintenance 149,735$ -$
(1) (2) (3) (4) (5) (6) (7)
Current Current Proposed Proposed
Line Annual Base Base Proposed Annual Base Base
No Description Lamps Rate Revenue Structure Lamps Rate Revenue
9 Sodium Vapor
10 70-Watt 0 1.37$ -$ N/A 0 -$ -$
11 100-Watt 0 1.28$ -$ N/A 0 -$ -$
12 200-Watt 0 1.27$ -$ N/A 0 -$ -$
13 250-Watt 396 1.37$ 543$ N/A 0 -$ -$ 14 400-Watt 0 1.37$ -$ N/A 0 -$ -$
15 Total Lamp Charges 396 543$ 0 -$
16 Service Charge 61 3.36$ 205$ N/A 0 -$ -$
17 Energy Charge
18 Per kWh 78,103 0.05125$ 4,003$ N/A 0 -$ -$
19 BM - Customer-Owned, Metered, Maintenance 4,750$ -$
(1)(2)(3)(4)(5)(6)(7)
Current Current Proposed Proposed
Line Base Base Proposed Base Base
No Description Use Rate Revenue Structure Use Rate Revenue
01 Energy Charge Energy Charge
2 Per kWh 10,704,238 0.05240$ 560,902$ Per kWh 12,919,225 0.06339$ 818,950$
3 C - Customer-Owned, Non-Metered, No Maintenance 560,902$ 818,950$
(1)(2)(3)(4)(5)(6)(7)
Current Current Proposed ProposedLineBaseBase Proposed Base Base
No Description Use Rate Revenue Structure Use Rate Revenue
0
4 Service Charge 14,746 3.36$ 49,547$ Service Charge 14,807 5.59$ 82,771$
5 Energy Charge Energy Charge
6 Per kWh 6,609,543 0.05125$ 338,739$ Per kWh 6,687,646 0.06339$ 423,930$
7 CM - Customer-Owned, Metered, No Maintenance 388,286$ 506,701$
Street Lighting Service (cont'd)
Schedule 41
C - Customer-Owned, Non-Metered, No Maintenance
CM - Customer-Owned, Metered, No Maintenance
IPC-E-23-11
IPC-E-23-11
Street Lighting Service (cont'd)Schedule 41
B - Customer-Owned, Non-Metered, Maintenance
BM - Customer-Owned, Metered, Maintenance
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
Settlement Stipulation
Street Lighting Service (cont'd)
Schedule 41
A - Com an -Owned, Non-Metered, Maintenance
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement StipulationIPC-E-23-11
Idaho Power Com an
State of IdahoCalculation of Proposed Rates
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 34 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Traffic Control Signal Lighting Service
Schedule 42
(1) (2) (3) (4) (5)
Current Current Proposed Proposed
Line Base Base Base Base
No Description Use Rate Revenue Rate Revenue
0
1 No. of Billings 9,192.0 -$ -$ -$ -$
2 Energ 2,847,961 0.05815$ 165,609$ 0.07346$ 209,211$
3 Transfer Adjustment 32,659$ -$
4 Total Adjusted Base Revenue 198,268$ 209,211$
 END § § § § §END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 35 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-23-11
Clean Energy Your Way Program
Schedule 62 - Fixed Cost Component of the Retail Energy Charge, per kWh
Line Secondary Service Primay Service Transmission Service
No.Description Current Proposed Current Proposed Current Proposed
1 Fixed Cost Component of the Retail Energy Charge, per kWh
2 Summer (Jun-Aug)
3 On-Peak 3.6320 ¢0.6951 ¢2.4913 ¢0.6951 ¢2.4311 ¢0.6951 ¢
4 Mid-Peak 2.2898 ¢0.6951 ¢1.4049 ¢0.6951 ¢1.3753 ¢0.6951 ¢
5 Off-Peak 1.7156 ¢0.6951 ¢0.9503 ¢0.6951 ¢0.9258 ¢0.6951 ¢
6 Non-Summer (Sep-May)
7 On-Peak n/a 1.5569 ¢n/a 1.5569 ¢n/a 1.5569 ¢
8 Mid-Peak 1.9330 ¢1.5569 ¢1.1629 ¢1.5569 ¢1.1441 ¢1.5569 ¢
9 Off-Peak 1.4035 ¢1.5569 ¢0.7414 ¢1.5569 ¢0.7247 ¢1.5569 ¢
 END § §§END 
Exhibit No. 2
Case No. IPC-E-23-11
Settlement Stipulation
Page 36 of 36
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-23-11

STIPULATION AND SETTLEMENT

EXHIBIT 3

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
555, Demand Response 10,240,003$               
Total 484,907,243$             
Exhibit No. 3 ‐ PCA Components by Federal Energy Regulatory Commission ("FERC") Account
2023 Base Level NPSE
447, Surplus Sales (34,686,350)$              
Net 95% Accounts 260,218,486$             
100% Accounts (with 100% recovery in PCA)
555, PURPA 214,448,755$             
547, Other Fuel 119,653,675$             
555, Non‐PURPA Purchased Power 99,465,021$               
565, Third Party Transmission 10,263,139$               
95% Accounts (with 95% recovery in PCA)
501, Coal 65,523,000$               
536, Water for Power ‐$                             
Exhibit No. 3
Case No. IPC‐E‐23‐11
Settlement Stipulation
Page 1 of 1
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-23-11

STIPULATION AND SETTLEMENT

EXHIBIT 4

DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
Line Schedule FCC FCE FCC-DIST FCE-DIST
No.Uniform Tariff Schedules No.($/Cust./Yr.)($/kWh)($/Cust./Yr.)($/kWh)
1 Residential Service 1 & 3 739.20$ 0.067098$ 287.96$ 0.026138$
2 Residential Service - Time of Use: SONP 5 0.175878$ 0.083169$
3 Residential Service - Time of Use: SMP 5 0.087941$ 0.041586$
4 Residential Service - Time of Use: SOFP 5 0.043970$ 0.020792$
5 Residential Service - Time of Use: NSONP 5 0.085198$ 0.029266$
6 Residential Service - Time of Use: NSONP 5 0.056798$ 0.019511$
7 Residential Service - On Site Gen 6 654.72$ 0.070780$ 304.20$ 0.032886$
8 Small General Service 7 174.96$ 0.038463$ 24.02$ 0.005282$
9 Small General Service - On Site Gen 8 221.61$ 0.052308$ 63.33$ 0.014949$
739.20$ 287.96$
IDAHO POWER COMPANY
Development of Fixed Cost Adjustment Rate
2023 Test Year
Fixed Cost per Customer and Fixed Cost per Energy Rates Summary
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 1 of 6
A B C D E F
Rate COS Distribution and
Line Schedule Revenue Generation Transmission Customer Total Fixed Cost
No. Uniform Tariff Schedules No. Requirement Fixed Costs Fixed Costs Fixed Costs Fixed Costs % of Total Cost
B+C+D E ÷ A
1 Residential Service 1, 3 & 5 595,989,810 179,712,373 42,712,954 201,301,909 423,727,236 71.1%
2 Residential Service - On Site Gen 6 18,948,175 5,024,687 1,343,270 7,712,639 14,080,596 74.3%
3 Small General Service 7 19,148,903 3,779,129 913,896 10,081,743 14,774,768 77.2%
4 Small General Service - On Site Gen 8 97,520 18,475 5,309 54,629 78,413 80.4%
5 Large General Service 9 299,988,648 101,142,429 23,304,974 53,286,736 177,734,139 59.2%
6 Dusk/Dawn Lighting 15 689,884 - - 527,640 527,640 76.5%
7 Large Power Service 19 156,456,753 53,393,645 13,042,805 17,547,576 83,984,026 53.7%
8 Irrigation Service 24 186,121,685 55,943,213 13,958,560 61,742,902 131,644,675 70.7%
9 Unmetered Service 40 1,287,368 283,453 66,191 505,052 854,696 66.4%
10 Municipal Street Lighting 41 2,701,663 - - 1,964,746 1,964,746 72.7%
11 Traffic Control Lighting 42 417,200 68,169 21,077 238,799 328,046 78.6%
12 Special Contracts 26, 29, & 30 60,772,004 23,202,235 5,765,257 1,491,381 30,458,873 50.1%
13 Total FCA Tariff Schedules 1,342,619,613 880,157,854
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
IDAHO POWER COMPAN
Development of Fixed Cost Adjustment Rat
2023 Test Year
Table I
Class Cost of Service Functionalized Costs
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 2 of 6
A B C D E F G
Proposed COS Revenue Fixed Cost Fixed Cost
Line Schedule Base Rate Revenue Short-Fall Revenue % of Portion of Rev.
No. Uniform Tariff Schedules No. Revenue Requirement Difference Identifier Short-Fall Total Cost Short-Fall
Table I, Col. A A - B Table I, Col. E x F
1 Residential Service 1, 3 & 5 595,468,521 595,989,810 (521,290) X (521,290) 71.1% (370,618)
2 Residential Service - On Site Gen 6 13,683,222 18,948,175 (5,264,954) X (5,264,954) 74.3% (3,912,445)
3 Small General Service 7 18,690,670 19,148,903 (458,232) X (458,232) 77.2% (353,559)
4 Small General Service - On Site Gen 8 51,921 97,520 (45,599) X (45,599) 80.4% (36,665)
5 Large General Service 9 318,669,668 299,988,648 18,681,020
6 Dusk/Dawn Lighting 15 1,325,232 689,884 635,348
7 Large Power Service 19 157,333,066 156,456,753 876,313
8 Irrigation Service 24 170,746,050 186,121,685 (15,375,635) X (15,375,635) 70.7% (10,875,253)
9 Unmetered Service 40 1,307,805 1,287,368 20,438
10 Municipal Street Lighting 41 3,742,273 2,701,663 1,040,610
11 Traffic Control Lighting 42 209,219 417,200 (207,980) X (207,980) 78.6% (163,536)
12 Special Contracts 26, 29, & 30 61,391,966 60,772,004 619,962
13 Total Uniform Tariff Schedules 1,342,619,613 1,342,619,613 0 (21,873,690) (15,712,076)
Notes:
(a) The "Weighted Average Fixed Cost % of Short-Fall" is calculated by dividing the total "Fixed Cost Portion of Rev. Short-Fall" (Col. G)
by the total "Revenue Short-Fall" (Col. E)
Weighted Average
Fixed Cost %
of Short-Fall a
71.8%
IDAHO POWER COMPANY
Development of Fixed Cost Adjustment Rate
2023 Test Year
Table II
Identification of Interclass Revenue Subsidy
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 3 of 6
A B C D E F
2023 2023 Sales Share of Total
Line Schedule Avg. Number of Normalized COS COS Revenue Base Rate
No. Uniform Tariff Schedules No. Customers (kWh) Fixed Cost Variable Cost Short-Fall/Subsidy Revenue
Table I, Col. E ble I, Col. A - Col. Table II, Col. C C+D+E
1 Residential Service 1, 3 & 5 492,481 5,425,559,433 423,727,236 172,262,574 (521,290) 595,468,521
2 Residential Service - On Site Gen 6 13,288 122,912,496 14,080,596 4,867,579 (5,264,954) 13,683,222
3 Small General Service 7 30,401 138,285,160 14,774,768 4,374,135 (458,232) 18,690,670
4 Small General Service - On Site Gen 8 88 370,708 78,413 19,107 (45,599) 51,921
G H I J K L
COS Fixed Cost COS Fixed Cost Fixed Cost Total Fixed Cost Calculation of Calculation of
Line Schedule Revenue from Revenue from Share of Revenue Revenue from FCC FCE
No. Uniform Tariff Schedules No. Fixed Charges Energy Charges Short-Fall/Subsidy Energy Charges ($/Cust./Yr.) ($/kWh)
C-G E x 71.8 H + I J ÷ A J ÷ B
1 (Cont.) Residential Service 1, 3 & 5*59,310,348 364,416,888 (374,447) 364,042,441 739.20$ 0.067098$
2 (Cont.) Residential Service - On Site Gen 6 1,598,972 12,481,624 (3,781,865) 8,699,759 654.72$ 0.070780$
3 (Cont.) Small General Service 7 9,126,786 5,647,982 (329,153) 5,318,829 174.96$ 0.038463$
4 (Cont.) Small General Service - On Site Gen 8 26,268 52,145 (32,754) 19,391 221.61$ 0.052308$
* FCE not applicable to Residential I05; see I05 FCE determination
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
IDAHO POWER COMPANY
Development of Fixed Cost Adjustment Rate
2023 Test Year
Table III
Derivation of Fixed Cost per Customer and Fixed Cost per Energy Rates - Existing Customer
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 4 of 6
A B C D E F
2023 2023 Sales Distribution and
Schedule Avg. Number of Normalized Generation Transmission Customer Total
Uniform Tariff Schedules No. Customers (kWh) Fixed Costs Fixed Costs Fixed Costs Fixed Costs
C + D + E
1 Residential Service 1, 3 & 5 492,481 5,425,559,433 179,712,373 42,712,954 201,301,909 423,727,236
2 Residential Service Fixed Cost Proportions 1, 3 & 5 42.4% 10.1% 47.5% 100.0%
3 Residential On-Site Gen Service 6 13,288 122,912,496 5,024,687 1,343,270 7,712,639 14,080,596
4 Residential On-Site Gen Service Fixed Cost Proportions 6 35.7%9.5% 54.8% 100.0%
5 Small General Service 7 30,401 138,285,160 3,779,129 913,896 10,081,743 14,774,768
6 Small General Service Fixed Cost Proportions 7 25.6%6.2% 68.2% 100.0%
7 Small General Service On-Site Gen 8 88 370,708 18,475 5,309 54,629 78,413
8 Small General Service On-Site Gen Fixed Cost Proportions 8 23.6%6.8% 69.7% 100.0%
G H I J K L
Fixed Cost Distribution COS Fixed Cost Total Fixed Cost Calculation of Calculation of
Schedule Share of Revenue Share of Revenue from Revenue from FCC - Dist FCE - Dist
Uniform Tariff Schedules No. Short-Fall/Subsidy Short-Fall/Subsidy Fixed Charges Energy Charges ($/Cust./Yr.) ($/kWh)
(Proportion E) x G E + H - I J ÷ A J ÷ B
1 (Cont.) Residential Service 1, 3 & 5*(374,447) (177,890) 59,310,348 141,813,671 287.96$ 0.026138$
3 (Cont.) Residential On-Site Gen Service 6 (3,781,865) (2,071,515) 1,598,972 4,042,152 304.20$ 0.032886$
5 (Cont.) Small General Service 7 (329,153) (224,601) 9,126,786 730,356 24.02$ 0.005282$
7 (Cont.) Small General Service On-Site Gen 8 (32,754) (22,819) 26,268 5,542 63.33$ 0.014949$
* FCE not applicable to Residential I05; see I05 FCE determination
IDAHO POWER COMPANY
Development of Fixed Cost Adjustment Rate
2023 Test Year
Derivation of Fixed Cost per Customer and Fixed Cost per Energy Rates - New Customer
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 5 of 6
Existing New Customer
January 1, 2024 January 1, 2024
Avg Customers 986.31 986.31
FCC 739.20$ 287.96$
Total Fixed Cost Recovery 729,081$ 284,017.35$
FCE 0.067098$ 0.026138$
Total kWh 16,947,350 16,947,350
Fixed Cost Recovery in Energy 1,137,128$ 442,970$
Revenue Collection
Service Charge $118,444 118,444$
Summer Energy 567,154$ 567,154$
Non-Summer Energy 1,098,539$ 1,098,539$
Total Energy Collection 1,665,693$ 1,665,693$
Total Revenue 1,784,137$ 1,784,137$
Energy in Energy 528,565$ 1,222,723$
Summer Share Energy in Energy 162,441.84$ 375,774.68$
SONP Energy in Energy Rate 0.070594$ 0.163303$
SMP Energy in Energy Rate 0.035297$ 0.081652$
SOFP Energy in Energy Rate 0.017648$ 0.040826$
Check 162,441.84$ 375,774.68$
Non-Summer Energy in Energy 366,123.31$ 846,948.48$
NSONP Energy in Energy Rate 0.042589$ 0.098521$
NSOFP Energy in Energy Rate 0.028393$ 0.065680$
Check 366,123.31$ 846,948.48$
SONP Rate 0.246472$ 0.246472$
SMP Rate 0.123238$ 0.123238$
SOFP Rate 0.061618$ 0.061618$
NSONP Rate 0.127787$ 0.127787$
NSOFP Rate 0.085191$ 0.085191$
Implied SONP FCE Rate 0.175878$ 0.083169$
Implied SMP FCE Rate 0.087941$ 0.041586$
Implied SOFP FCE Rate 0.043970$ 0.020792$
Implied NSONP FCE Rate 0.085198$ 0.029266$
Implied NSOFP FCE Rate 0.056798$ 0.019511$
Summer OP FCE Differential Check 4.0 4.0
Summer MP FCE Differential Check 2.0 2.0
Non-Summer FCE Differential Check 1.5 1.5
Total FCE Collection Check 1,137,128$ 442,970$
IDAHO POWER COMPANY
Development of Fixed Cost Adjustment Rate
2023 Test Year
Derivation of Schedule 5 Fixed Cost per Customer and Fixed Cost per Energy Rates
Based Upon Settlement Stipulation - IPC-E-23-11 - Filed October 27, 2023
Exhibit No. 4
Case No. IPC-E-23-11
Settlement Stipulation
Page 6 of 6
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-23-11
STIPULATION AND SETTLEMENT
EXHIBIT 5
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
A B C D E F
A&G Expense
Rate Base Expenses Income Tax Exclusion Other Revenue Subsidiary Income
Source Ex. 32, L. 12 Ex. 32, L. 72 & 114 Table II, Col. E See Note 1 See Note 2 Ex. 35, L. 35
Generation Function
Energy-Related 53,590,613 494,807,700 594,489 1,831,853 34,958,629 1,759,534
G H I J K
Total Revenue
Current Return Desired Return Revenue Short-Fall Tax Gross-up Requirement
Source A x 7.805% (3) A x 7.247% (4)H-G I x 1.34662 - I B+C-D-E-F+H+J
Generation Function
Energy-Related 4,182,747 3,883,712 (299,036)(103,652)$460,632,233
Notes:
(1) Exhibit 31, Lines 499-558. The portion of the overall A&G exclusion associated with the energy-releated generation function (Table 5; FERC accounts 900-935; 416)
(2) Exhibit 32, Line 132
(3) Exhibit 35, Line 38
(4) Exhibit 35, Line 43
IDAHO POWER COMPANY
Development of Sales Based Adjustment Rate
2023 Test Year
Table I
Derivation of Energy-Related Generation Function Revenue Requirement
Exhibit No. 5
Case No. IPC‐E‐23‐11
Settlement Stipulation
Page 1 of 3
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
A B C D E
Energy-Related
Total Federal Total State Income Generation Function Allocated Income
Income Tax Tax Rate Base Total Rate Base Taxes
Source Ex. 35, L. 28 Ex 35, L. 29 Ex. 32, L. 12 Ex. 32, L. 60 (A + B) x (C / D)
Generation Function
Energy-Related 43,734,786 (1,399,401)53,590,613 3,816,351,478 594,489
IDAHO POWER COMPANY
Development of Sales Based Adjustment Rate
2023 Test Year
Table II
Derivation of Energy-Related Generation Function Revenue Requirement
Exhibit No. 5
Case No. IPC‐E‐23‐11
Settlement Stipulation
Page 2 of 3
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9
A B C
Energy-Related Generation 2023 Test Year Idaho Sales Based
Function Revenue Retail Sales Adjusted Rate
Requirement (MWh)($/MWh)
Source Table I, Col K.Ex. 37, L. 106 A / B
Generation Function
Energy-Related $460,632,233 14,907,835 $30.90
IDAHO POWER COMPANY
Development of Sales Based Adjustment Rate
2023 Test Year
Table III
Derivation of Energy-Related Generation Function Revenue Requirement
Exhibit No. 5
Case No. IPC‐E‐23‐11
Settlement Stipulation
Page 3 of 3
DocuSign Envelope ID: F4B2D902-4D60-4CE4-98BC-1D74D15FE6E9

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-23-11

IDAHO POWER COMPANY

ATTACHMENT NO. 2

PROPOSED TARIFFS

Idaho Power Company Original Sheet No. i
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. i
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, ID
IDAHO PUBLIC UTILITIES COMMISSION
TARIFF NO. 30
GENERAL RULES, REGULATIONS AND RATES
APPLICABLE TO ELECTRIC SERVICE IN THE TERRITORY
SERVED FROM THE COMPANY’S INTERCONNECTED SYSTEM
IN IDAHO
Idaho Power Company Original Sheet No. ii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. ii
IDAHO Issued by IDAHO POWER COMPANY
Issued Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, ID
GENERAL RULES AND REGULATIONS INDEX
SHEET
RULE TITLE NUMBER
Title Page ........................................................................................................................... i
Index Page ................................................................................................................. ii -- iv
Rule A Introduction ................................................................................................................... A-1
Rule B Definitions ............................................................................................................ B-1 -- B-2
Rule C Service and Limitations ....................................................................................... C-1 -- C-2
Rule D Metering .............................................................................................................. D-1 -- D-2
Rule E Master Metering Standards ........................................................................................... E-1
Rule F Service Establishment and Discontinuance .................................................................. F-1
Rule G Billings ................................................................................................................ G-1 -- G-2
Rule H New Service Attachments and Distribution Line Installations or Alterations H-1 -- H-14
Rule I Budget Pay Plans ................................................................................................... I-1 -- I-2
Rule J Continuity, Curtailment and Interruption of Electric Service .................................. J-1 – J-4
Rule K Customer’s Load and Operations ........................................................................ K-1 -- K-2
Rule L Deposits ............................................................................................................... L-1 -- L-2
Rule M Facilities Charge Service .................................................................................... M-1 -- M-3
Idaho Power Company Original Sheet No. iii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective –January 1, 2024 1221 West Idaho Street, Boise, ID
SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER
1 Residential Service Standard Plan ........................................................................ 1-1 – 1-2
3 Master-Metered Mobile Home Park Residential Service................................................ 3-1
5 Residential Service Time-of-Use Plan (Optional) .................................................. 5-1 – 5-2
6 Residential Service On-Site Generation ............................................................... 6-1 – 6-6
7 Small General Service .......................................................................................... 7-1 – 7-2
8 Small General Service On-Site Generation .......................................................... 8-1 – 8-5
9 Large General Service .......................................................................................... 9-1 – 9-5
15 Dusk to Dawn Customer Lighting ...................................................................... 15-1 – 15-2
19 Large Power Service ......................................................................................... 19-1 – 19-7
20 Speculative High-Density Load ......................................................................... 20-1 – 20-8
23 Irrigation Peak Rewards Program (Optional) .................................................. 23-1 – 23-10
24 Agricultural Irrigation Service ............................................................................ 24-1 – 24-6
26 Micron Technology, Inc. Special Contract ......................................................... 26-1 – 26-2
29 J.R. Simplot (Pocatello, Idaho) Special Contract ......................................................... 29-1
30 Department of Energy Special Contract ............................................................ 30-1 – 30-2
31 Supply of Standby Electric Service for Amalgamated Sugar Company ....................... 31-1
32 J.R. Simplot (Caldwell, Idaho) Special Contract........................................................... 32-1
33 Brisbie, LLC Special Contract ........................................................................... 33-1 – 33-4
34 Lamb Weston, Inc. ............................................................................................ 34-1 – 34-4
40 Non-Metered General Service .......................................................................... 40-1 – 40-2
41 Street Lighting Service ...................................................................................... 41-1 – 41-4
42 Traffic Control Signal Lighting Service ......................................................................... 42-1
45 Standby Service ................................................................................................ 45-1 – 45-5
46 Alternate Distribution Service ............................................................................ 46-1 – 46-4
54 Fixed Cost Adjustment ...................................................................................... 54-1 – 54-2
55 Power Cost Adjustment ..................................................................................... 55-1 – 55-3
61 Payment for Home Wiring Audit ................................................................................... 61-1
62 Clean Energy Your Way Program (Optional) .................................................... 62-1 – 62-5
66 Miscellaneous Charges ..................................................................................... 66-1 – 66-3
68 Interconnections to Customer Distributed Energy Resources......................... 68-1 – 68-28
72 Generator Interconnections to PURPA Qualifying Facility Sellers .................. 72-1 – 72-28
Idaho Power Company Original Sheet No. iv
cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. iv
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, ID
SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER
73 Cogeneration and Small Power Production Schedule – Idaho ....................... 73-1 – 73-10
79 Weatherization Assistance for Qualified Customers .................................................... 79-1
81 Residential Air Conditioner Cycling Program (Optional) ................................... 81-1 – 81-3
82 Flex Peak Program (Optional) ........................................................................... 82-1 – 82-7
84 Customer Energy Production Net Metering Service.......................................... 84-1 – 84-6
86 Cogeneration and Small Power Production Non-Firm Energy .......................... 86-1 – 86-7
87 Intermittent Generation Integration Charges ................................................... 87-1 – 87-24
89 Unit Avoided Energy Cost for Cogeneration and Small Power Production .................. 89-1
91 Energy Efficiency Rider ................................................................................................ 91-1
95 Adjustment for Municipal Franchise Fees ......................................................... 95-1 – 95-2
96 Blaine County Surcharge to Fund the Undergrounding of Certain Facilities ................ 96-1
98 Residential and Small Farm Energy Credit ....................................................... 98-1 – 98-2
Idaho Power Company Original Sheet No. A-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. A-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE A
INTRODUCTION

These Rules and Regulations are a part of the Tariff of Idaho Power Company and apply to the
Company and every Customer to whom service is supplied; provided, that in case of conflict between
these Rules and Regulations and the provisions of any schedule of this Tariff, the provisions of such
schedule will govern as to service supplied thereunder.

Idaho Power Company Original Sheet No. B-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. B-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE B
DEFINITIONS

The terms listed below, which are used frequently in this Tariff, will have the stated meanings:

Billing Period is the period intervening between meter readings and shall be approximately 30 days.
However, Electric Service covering 27-36 days inclusive will be considered a normal Billing Period.

Commission refers to the Idaho Public Utilities Commission.

Company refers to Idaho Power Company.

Customer is the individual, partnership, association, organization, public or private corporation,
government or governmental agency receiving or contracting for Electric Service.

Demand is the average kilowatts (kW) or horsepower (HP) supplied to the Customer during the 15-
consecutive-minute period of maximum use during the Billing Period, as shown by the Company's meter,
or determined in accordance with the demand clause in the schedule under which service is supplied. In
no event, however, will the maximum demand for the Billing Period be less than the demand determined
as specified in the schedule.

Electric Service is the availability of power and energy in the form and at the voltage specified in
the Idaho Electric Service Request or agreement, irrespective of whether electric energy is actually
utilized, measured in kilowatt-hours (kWh).

Month (unless calendar month is stated) is the approximate 30-day period coinciding with the Billing
Period.

Normal Business Hours are 8:00 a.m. to 5:00 p.m., Monday through Friday, excluding holidays
observed by the Company. All times are stated in Mountain Time. Notice of office closures for holidays
are posted, in advance, at the Company office entrances.

Point of Delivery is the junction point between the facilities owned by the Company and the facilities
owned by the Customer; OR the point at which the Company's lines first become adjacent to the Customer's
property; OR as otherwise specified in the Company's Tariff.

Power Factor is the percentage obtained by dividing the maximum demand recorded in kW by the
corresponding kilovolt-ampere (kVA) demand established by the Customer.

Premises is a building, structure, dwelling, suite, or residence of the Customer that is separated by
a demising wall. If the Customer uses several buildings, structures or suites in the operation of a single
integrated commercial, industrial, or institutional enterprise, the Company may consider all such buildings,
structures or suites that are in proximity to each other to be the Premises, even though intervening
ownerships or public thoroughfares exist.

Idaho Power Company Original Sheet No. B-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. B-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE B
DEFINITIONS
(Continued)

Service Level is defined as follows:

Secondary Service is service taken at 480 volts or less, or where the definitions of Primary Service
and Transmission Service do not apply. The Company is responsible for providing the transformation of
power to the voltage at which it is to be used by the Customer taking Secondary Service.

Primary Service is service taken at 12.5 kilovolts (kV) to 34.5 kV. Customers taking Primary Service
are responsible for providing the transformation of power to the voltage at which it is to be used by the
Customer.

Transmission Service is service taken at 44 kV or higher. Customers taking Transmission Service
are responsible for providing the transformation of power to the voltage at which it is to be used by the
Customer.

Idaho Power Company Original Sheet No. C-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. C-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE C
SERVICE AND LIMITATIONS

1. Rates and Tariff. Service supplied by the Company will be in accordance with the Tariff on
file with the state regulatory authority having jurisdiction, and as in effect at the time service is supplied.
All service rates and agreements are subject to the continuing jurisdiction and regulation of such
authority, as provided by law.

When any municipal corporation or other local taxing agency imposes on the Company any
franchise, occupation, sales, license, excise, business, operating, privilege, or use of street tax or
charge based upon meters or Customers, or upon electricity sold or the receipts or income therefrom,
the prorate amount thereof will be billed to all Customers in the area or locality in which such tax or
charge applies and will be separately stated on, and added to, their regular billing.

2. Supplying of Service. Service will be supplied under a given schedule only to Points of
Delivery as are adjacent to facilities of the Company, adequate and suitable as to capacity and voltage for
the service desired and under the schedule applicable thereto. The Company will not be obligated to
construct extensions or install additional service facilities except in accordance with Rule H and to the
Company’s construction standards. In instances where Rule H is not applicable, special agreements
between the Customer and the Company may be required.

3. Service Application. The Company will normally accept an application for service from the
Customer by telephone, through the Company’s website or by other oral communication. The Company
may however, at its discretion, require the Customer to sign an application requesting service.

4. Choice of Schedules. The Company's schedules are designed to provide monthly rates for
service supplied to the Customer on an annual basis. The Customer may elect to take service under any
of the schedules applicable to this annual service requirement, and the Company will endeavor to assist
in the selection of the appropriate schedule most favorable to the Customer. Changing of schedules will
occur only when the characteristics of the Customer's usage change such that another applicable
schedule is deemed more favorable to the Customer when applied to the Customer's annual service
requirements. Customers receiving service under Schedules 7, 8, 9, 19, and 20 will be reviewed on a
monthly basis under the provisions established in the Applicability section of each of these schedules.

5. Point of Delivery Service Requirements. A Customer may be served at more than one
Point of Delivery at the same Premises if practicable, unless otherwise specified in a schedule. Service at
each Point of Delivery at the same Premises will be offered under the appropriate schedule. The
Customer's request for service at an additional Point of Delivery will be subject to the applicable line
extension rules of the Company. The Company may refuse to provide service at more than one Point of
Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery
cannot be provided without jeopardizing the safety and reliability of the Company's system or service to
the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the
same Premises will not be interconnected electrically.

Idaho Power Company Original Sheet No. C-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. C-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE C
SERVICE AND LIMITATIONS
(Continued)

5. Point of Delivery Service Requirements (Continued)

Where separate Points of Delivery exist for supplying service to a Customer at a single
Premises or separate meters are maintained for measurement of service to a Customer at a single
Premises, the meter readings will not be combined or aggregated for any purpose except for
determining if the Customer's total power requirements exceed 20,000 kW. Special contract
arrangements will be required when a Customer's aggregate power requirement exceeds 20,000 kW.

Service delivered at low voltage (600 volts or under) will be supplied from the Company's
distribution system to the outside wall of the Customer's building service pole or post unless an
exception is granted by the Company and the City or State Electrical Inspector.

The Customer's facilities will be installed and maintained in accordance with the requirements of
the National Electrical Code.

6. Limitation of Use. A Customer will not resell electricity received from the Company to any
person except (1) where the Customer is owner, lessee, or operator of a commercial building, shopping
center, apartment house, mobile home court, or other multi-family dwelling where the use has been sub-
metered prior to July 1, 1980, and the use is billed to tenants at the same rates that the Company would
charge for service, unless the Commission authorizes alternative procedures, or (2) where the electricity
is purchased from a public utility (as defined in Idaho Code § 61-129) to charge the batteries of an electric
motor vehicle as provided by order or rule of the Commission.

A Customer's wiring will not be extended or connected to furnish service to more than one
building or place of use through one meter, even though such building, property, or place of use is
owned by the Customer. This provision is not applicable where the Customer's residence or business
consists of one or more adjacent buildings or places of use located on the same Premises or operated
as an integral unit, under the same name and carrying on parts of the same residence or business.

7. Rights of Way. The Customer shall, without cost to the Company, grant the Company a
right of way for the Company's lines and apparatus across and upon the property owned or controlled by
the Customer, necessary or incidental to the supplying of Electric Service and shall permit access thereto
by the Company's employees at all reasonable hours. The Customer shall also grant the Company
access to permit the Company to trim trees and other vegetation to the extent necessary to avoid
interference with the Company’s lines and to protect public safety.

Idaho Power Company Original Sheet No. D-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. D-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE D
METERING

1. Meter Installations. The Company will install and maintain the metering equipment
required by the Company to measure power and energy supplied to the Customer. Meter installations
will be done at the Company's expense except as specified below or otherwise specified in a schedule.
Customer provisions for meter installations will be made in conformance with Company specifications,
the National Electrical Code, and/or applicable state or municipal requirements.

a. Instrument Transformer Metering. When instrument transformer metering is
requested by the Customer but not required by the Company at the time of the initial meter
installation, the Customer will be required to pay the cost of such metering equipment and its
installation in accordance with the charges specified in Schedule 66. When a Customer requests
instrument transformer metering not required by the Company at a time other than at the time of
the initial meter installation, work order costs will apply.

b. Load Profile Metering. The Company will install, at the Customer’s request, the
metering equipment necessary to provide load profile information. When Load Profile Metering
service is requested by the Customer but not provided by the Company as part of its standard meter
installation, the Customer will pay work order costs for the installation of all equipment required to
provide such service. The options available under Load Profile Metering service include: Pulse
Output Service, which provides limited kWh and kW load information; Load Profile Recording
Service, which downloads load characteristics and information on a delayed basis; and Enhanced
Metering Information Service, which provides real-time access to load characteristics and
information. Customers requesting that the Company provide Load Profile Metering service are
responsible for providing, at their own expense, a hard-wired or wireless connection to each
metering point, and all such connection equipment will be owned by the Customer unless the
configuration of metering equipment necessitates otherwise.

The Company shall not be liable to any Customer or any other persons for any loss or
damage incurred resulting from the supply or interruption of any Load Profile Metering service. The
Company does not warrant or guarantee the accuracy, reliability, validity or usability of the
information or data provided by its Load Profile Metering service, and Customers receiving any such
Load Profile Metering service voluntarily assume all responsibility and risk in use of such service’s
information or data.

c. Primary Voltage Metering. The Company will install, at its own expense, a
maximum of one primary voltage meter at a single Premises to record usage taken at 12.5 kV or 34.5 kV.
In all other circumstances, work order costs will apply.

2. Measurement of Energy. Except as otherwise specifically provided, all energy delivered by
the Company will be billed according to measurement by meters located at or near the Point of Delivery.

If the Company is unable to obtain a Customer's meter reading(s), the Company may estimate
the meter reading(s) for the Billing Period on the basis of the Customer's previous use, season of the
year and use by similar Customers of the same class in that service area. Bills rendered based on an
estimated monthly read, or when a Billing Period includes more than twenty-four unscaled hourly reads,
will be designated as estimated on the bill. The amount of such estimated bill will be subsequently
adjusted, when practicable, when the next actual reading is obtained.
Idaho Power Company Original Sheet No. D-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. D-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE D
METERING
(Continued)

3. Failure to Register. If the Company's meters fail to register at any time, the service delivered
and energy consumed during such period of failure will be determined by the Company on the basis of the
best available data. If any appliance or wiring connection, or any other device, is found on the Customer's
Premises which prevents the meters from accurately recording the total amount of energy used on the
Premises, the Company may at once remove any such wiring connection or appliance, or device, at the
Customer's expense, and will estimate the amount of energy so consumed and not registered as accurately
as it is able so to do, and the Customer will pay for any such energy within 5 days after being billed, in
accordance with such estimate.

4. Meter Tests. The Company will test and inspect its meters from time to time and maintain
their accuracy of registration in accordance with generally accepted practices and the rules and regulations
established by the Idaho Public Utilities Commission. The Company will, without charge, test the accuracy
of registration of a meter upon request of a Customer, provided that the Customer does not request such
a test more frequently than once in a 12-month period. If more than one requested test is performed within
a 12-month period, the Customer will be required to pay in advance the cost of a special meter test as
specified in Schedule 66. The Company will refund the amount paid by the Customer for the test if the
results of the test show the average registration error of the meter exceeds ±2 percent.

5. Transformer Losses. When delivery of service is on the primary side of the Customer's
transformers, the Company may install its meters on the secondary side of the transformers, and, unless
otherwise provided in the schedule, in determining the monthly consumption of power and energy,
transformer losses and other losses occurring between the Point of Delivery and the meters will be
computed and added to the reading of such meters.

6. Meter Reading. Meters will be read to the last kWh registered, normally at intervals of
approximately 30 days for monthly register reads and daily for hourly interval reads. In no case will the
meter reading interval exceed 45 days.
Idaho Power Company Original Sheet No. E-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. E-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE E
MASTER METERING STANDARDS

1. Definitions:

a. Tenant--Mobile Home Park. A tenant of a mobile home park is a person defined as
a resident and not a transient by the Manufactured Home Residency Act, Section 55-2001 et seq.,
Idaho Code, and in particular by Section 55-2003(16) and 55-2003(19), Idaho Code.

b. Tenant--Multi-Unit Residential or Commercial Building. A tenant of a multi-unit
residential building is a person who is not a transient and who intends to reside in or be a commercial
tenant in one of the building's units for a period of not less than one month.

2. Master-Metering and Individual Metering in Mobile Home Parks:

a. Master Metering Prohibited. Master-metering, whether or not in conjunction with
sub-metering of electric service by the park operator, is prohibited for any mobile home park
connected for service by the Company after July 1, 1980. After that date, tenants (excluding
transients) of mobile home parks must be individually metered and billed by the Company.

b. Exception for Sub-Metered Parks. Any mobile home park connected for service on
or before July 1, 1980, whose spaces for non-transient tenants have been fully sub-metered for
electricity by the park owners need not be individually metered by the Company. A mobile home
park sub-metered by the park operator must charge each of their tenants the same rate for electric
service that a Customer of the Company would be charged if the tenant were directly metered and
billed by the Company under Schedule 3 – Master-Metered Mobile Home Park – Residential
Service. Testing of sub-meters will be at the park operator's expense.

3. Master-Metering and Individual Metering in Multi-Occupant Residential Buildings. Non-
transient tenants of multi-occupant residential buildings connected for electric service after July 1,
1980, will be individually metered and billed by the Company if the dwelling units for such tenants
contain an electric space heating, water heating, or air-conditioning (space cooling) unit that is not
centrally controlled and for which said tenants individually control electric usage.

4. Master-Metering and Individual Metering in Commercial Buildings and Shopping Centers.
Commercial buildings and shopping centers connected for electric service after July 1, 1980, may
not be master-metered if the units for non-transient tenants contain an electric space heating, water
heating, or air-conditioning (space cooling) unit that is not centrally controlled and for which the
unit's tenants individually control electric usage. Any non-transient tenants in otherwise master-
metered buildings will be individually metered and billed by the Company if the tenant’s electric load
is significantly greater than that of the other tenants in the building or shopping center, or exceeds
the individual metering threshold found in the Company's Tariff.

Idaho Power Company Original Sheet No. F-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. F-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
RULE F
SERVICE ESTABLISHMENT AND
DISCONTINUANCE
1. Service Establishment. A Service Establishment Charge as specified in Schedule 66,
unless otherwise specified in a different schedule, will be assessed upon initiating metered service with
the Company if service at the Point of Delivery is currently energized. The applicable charge will be
billed with the first regular bill.
a. Owners or managers of rental property that arrange with the Company to provide
continuous service between tenants will not be assessed a Service Establishment Charge when
the service reverts to the responsible party as arranged.
2.Continuous Service. At the request of owners or managers of rental property, the
Company will provide continuous service between tenant occupancy. A Continuous Service Reversion
Charge, as specified in Schedule 66, will be assessed each time service reverts to the responsible
party as arranged.
3.Service Connection. Where service at the specified Point of Delivery is currently
disconnected from the Company’s system, a Service Connection Charge or Remote Service
Connection Charge, as specified in Schedule 66, will be assessed at the time service is connected. The
applicable charge will be billed with the first regular bill. The Service Connection Charge applies to all
service connections, except for remote service connections, for both metered and unmetered service.
The Remote Service Connection Charge applies only to those service connections where remote
capability of reconnection is available and when service is connected remotely. The Service
Establishment Charge does not apply when service is reconnected.
4. Service Discontinuance. At the Customer’s request, the Company will disconnect service
during normal working hours. There is no charge for discontinuing service.
a. When a Customer requests service be discontinued, service will not be
disconnected if another party has agreed to accept responsibility for service at the Point of
Delivery. Upon initiating service, the Customer requesting service will be billed a Service
Establishment Charge in accordance with this rule.
5.Termination Practices. The Company's practices relating to Termination of Service are
governed by the Utility Customer Relations Rules (UCRRs) of the Idaho Public Utilities Commission, in
effect at the time the event occurred which required application of the UCRRs. If the Company's Rules
and Regulations on file with the Idaho Public Utilities Commission contain provisions which conflict with
the UCRRs, the provisions of the respective UCRRs supersede those included in the Company's Rules
and Regulations.
6.Field Visit. A Field Visit Charge, as specified in Schedule 66, will be assessed when a
Company representative visits a service address intending to disconnect or connect service, but due to
Customer action, the Company representative is unable to complete the disconnection or connection at
the time of the visit. Examples of Customer action include, but are not limited to, a) the Customer
making a payment at the door, or b) obstructing the Company’s access to the Customer’s meter or
threatening to cause or causing physical harm to the Company representative.
Idaho Power Company Original Sheet No. G-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. G-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
RULE G
BILLINGS
1. Fractional Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the Energy Charge for service under Schedules 1, 3, 5, 6, 7, 8, 9, 19, 20, or 24 will be
calculated using actual meter readings. The Energy Charge for service provided under Schedule 40 will
be determined using the daily kWh calculated on the basis of load size and number of units served
multiplied by the actual number of days since the account was opened or since the previous billing, where
appropriate. The proration of the applicable Demand Charge, Basic Charge, Facilities Charge, and
Service Charge specified in the appropriate schedule will be calculated by dividing the charge by 30 and
multiplying the result by the actual number of days since the account was opened or since the previous
meter reading, where appropriate. However, the prorated Service Charge for Schedules 1, 3, 5, 6, 7, 8,
9, 19, 20, or 24 or the Minimum Charge for Schedule 40, will be no less than the amount specified in
Schedule 66. For Schedule 15, the proration of the applicable Monthly Charge will be calculated by
dividing the charge by 30 and multiplying the result by the actual number of days since the account was
opened or the previous billing, where appropriate.
2.Corrected Billings. Whenever it is determined that a Customer was billed under an
inappropriate schedule, the Customer will be rebilled under the appropriate schedule; however, if the
Company selected the schedule on the basis of available information and acted in good faith, the Company
will not be required to rebill or adjust billings. When the customer has been overcharged, the rebilling period
will be no more than the 3-year period as provided by Idaho Code § 61-642. When the customer has been
undercharged, the rebilling period shall be limited to six months unless a reasonable person should have
known of the inappropriate billing, in which case the rebilling period may be extended for a period not to
exceed three years, except for counties in which case the rebilling period may not exceed one year as
provided by Idaho Code § 31-1501.
If the average error for any meter test exceeds ±2 percent, corrected billings will be
prepared. The corrected billings will not exceed 6 months if the time when the malfunction or error began
is unknown. If the time when the malfunction or error began is known and the customer was overcharged,
the corrected billings will be from that time, but will not exceed the 3-year period as provided by Idaho Code
§ 61-642. If the time when the malfunction or error began is known and the customer was undercharged,
the Company will rebill for a period of six months unless a reasonable person should have known of the
inaccurate billing, in which case the rebilling may be extended for a period not to exceed three years. If an
under-billing occurs, the Company will offer and enter into reasonable payment arrangements with the
Customer. For any over-billings, the Customer will have the choice of a refund or a credit on future bills.
3.Due Dates. The Company's practices relating to Due Dates are governed by the Utility
Customer Relations Rules (UCRRs) of the Idaho Public Utilities Commission, in effect at the time the
event occurred which required application of the UCRRs. If the Company's Rules and Regulations on file
with the Idaho Public Utilities Commission contain provisions which conflict with the UCRRs, the
provisions of the respective UCRRs supersede those included in the Company's Rules and Regulations.
4.Returned Checks. Checks or payments remitted by Customers in payment of bills are
accepted conditionally. A Returned Check Charge, as specified in Schedule 66, will be assessed to the
Customer for handling each check or payment upon which payment has been refused by the bank.
Idaho Power Company Original Sheet No. G-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. G-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE G
BILLINGS
(Continued)

5. Late Payments. A Late Payment Charge, as provided in Schedule 66, may be levied against
any delinquent account except for accounts of agencies and taxing districts of the State of Idaho as
described in paragraph 6 of this schedule. All payments received by the billing date will apply to the
Customer's account prior to calculating the Late Payment Charge. Payments will satisfy the oldest portion
of the billing first and the current portion of the billing last.

Late Payment Charges will continue to accrue against unpaid disputed bill amounts. If the
dispute is resolved in favor of the Customer, all disputed charges plus any associated Late Payment
Charges will be deleted from the Customer’s account. If the dispute is resolved in favor of the Company,
all disputed charges plus any associated Late Payment Charges will become due and payable.

6. Late Payments for Agencies and Taxing Districts of the State of Idaho. Under the authority
of Idaho Code § 67-2302, an agency or taxing district, as defined within Idaho Code § 63-3101, of the State
of Idaho has 60 days from the date that the bill is received to pay that bill. If a state agency or taxing district
does not pay the bill within the 60-day period, all of the provisions of Idaho Code § 67-2302 will apply and
the Late Payment Charge as specified in Schedule 66 will be levied against the delinquent account.

Any state agency or taxing district that claims that it falls within the provisions of Idaho Code
§ 67-2302 must notify the Company in writing of such claim.

7. Temporary Suspension of Demand. When the Customer is obliged temporarily to suspend
operation due to strikes, actions of any governmental authority, acts of God or the public enemy, the
Customer may procure a proration of the monthly Billing Demand based upon the period of such
suspension by giving immediate written notice to the Company. However, all monthly Minimum Charges
and/or obligations will continue to apply as specified in the applicable schedule or a written agreement.

Idaho Power Company Original Sheet No. H-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. H-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS

This rule applies to requests for electric service under Schedules 1, 3, 5, 6, 7, 8, 9, 19, 20, 24, 45,
and 46 that require the installation, alteration, relocation, removal, or attachment of Company-owned
distribution facilities. New construction beyond the Point of Delivery for Schedule 9 or Schedule 19 is
subject to the provisions for facilities charges under those schedules. This rule does not apply to
transmission or substation facilities, or to requests for electric service that are of a speculative nature.

1. Definitions

Additional Applicant is a person or entity whose Application requires the Company to provide new
or relocated service from an existing section of distribution facilities with a Vested Interest.

Allowance is the portion of a Work Order Cost’s Terminal Facilities funded by the Company.

Alteration is any change or proposed change to existing distribution facilities. An alteration may
include Relocation, Upgrade, Conversion, and/or removal.

Applicant is a person or entity whose Application requires the Company to provide new or
relocated service from distribution facilities that are free and clear of any Vested Interest.

Application is a request by an Applicant or Additional Applicant for new electric service from the
Company. The Company, at its discretion, may require the Applicant or Additional Applicant to
sign a written application.

Company Betterment is that portion of the Work Order Cost of a Line Installation and/or Alteration
that provides a benefit to the Company not required by the Applicant or Additional Applicant.
Increases in conductor size and work necessitated by the increase in conductor size are
considered a Company Betterment if the Connected Load added by the Applicant or Additional
Applicant is less than 100 kilowatts. If, however, in the Company’s discretion, it is determined that
the additional Connected Load added by the Applicant or Additional Applicant, even though less
than 100 kilowatts, is (1) located in a remote location, or (2) a part of a development or project
which will add a load greater than 100 kilowatts, the Company will not consider the work
necessitated by the load increase to be a Company Betterment.

Connected Load is the total nameplate kW rating of the electric loads connected for commercial,
industrial, or irrigation service. Connected Load for residences is considered to be 25 kW for
residences with electric space heat and 15 kW for all other residences.

Conversion is a request by a customer to replace overhead facilities with underground facilities.

Cost Quote is a written cost estimate provided by the Company that must be signed and paid by
the Applicant or Additional Applicant prior to the start of construction. Cost Quotes are derived
from Work Order Cost estimates.

Easement is the Company’s legal right to use the real property of another for the purpose of
installing or locating electric facilities.
Idaho Power Company Original Sheet No. H-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Fire Protection Facilities are water pumps and other fire protection equipment, served separately
from the Applicant's other electric load, which operate only for short periods of time in emergency
situations and/or from time to time for testing purposes.

Line Installation is any installation of new distribution facilities owned by the Company. Line
Installations are exclusive of Service Attachments and Terminal Facilities and are eligible for
Vested Interest Refunds.

Line Installation Charge is the partially refundable charge assessed to an Applicant or Additional
Applicant whenever a Line Installation is built for that individual.

Local Improvement District is an entity created by an authorized governing body under the
statutory procedures set forth in Idaho code, Title 50, Chapter 17 or Idaho Code § 40-1322. For
the purpose of Rule H, the term LID also includes Urban Redevelopment projects set forth in
Idaho Code, Title 50, Chapter 20.

Multiple Occupancy Projects are projects that are intended to be occupied by more than four
owners or tenants. Examples include, but are not limited to, condominiums and apartments.

Prior Right of Occupancy is a designated area within the public road right-of-way where the
Company and the Public Road Agency have agreed that the costs of the Relocation of facilities
in the designated area will be borne by the Public Road Agency. For example, a Prior Right of
Occupancy may be created when the Public Road Agency expands the public road right-of-way
to encompass a Company Easement without compensating the Company for acquiring the
Easement but the parties agree in writing that the subsequent Relocation of distribution facilities
within the designated area will be borne by the Public Road Agency.

Private Beneficiary is any individual, firm or entity that provides funding for road improvements
performed by a Public Road Agency or compensates the Company for the Relocation of
distribution facilities as set forth in Section 10. A Private Beneficiary may include, but is not limited
to, real estate developers, adjacent landowners, or existing Customers of the Company.

Public Road Agency is any state or local agency which constructs, operates, maintains or
administers public road rights-of-way in Idaho, including where appropriate the Idaho
Transportation Department, any city or county street department, or a highway district.
Idaho Power Company Original Sheet No. H-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. H-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Relocation is a change in the location of existing distribution facilities.

Residence is a structure built primarily for permanent domestic dwelling. Dwellings where tenancy
is typically less than 30 days in length, such as hotels, motels, camps, lodges, clubs, and
structures built for storage or parking do not qualify as a Residence.

Service Attachment is the interconnection between the Company’s distribution system and the
Applicant’s or Additional Applicant’s Point of Delivery.

Shared Terminal Facilities is when two or more existing Residential, General Service, or Irrigation
Customers receive service from any portion of the same Terminal Facilities.

Standard Terminal Facilities are the overhead Terminal Facilities the Company considers to be
most commonly installed for overhead single phase and three phase services. Single phase
Standard Terminal Facilities include the cost of providing and installing one overhead #2
aluminum service conductor and one 25 kVA transformer. Three phase Standard Terminal
Facilities include the cost of providing and installing one overhead #2 aluminum service conductor
and three 15 kVA transformers.

Subdivision is the division of a lot, tract, or parcel of land into two or more parts for the purpose
of transferring ownership or for the construction of improvements thereon that is lawfully
recognized, platted and approved by the appropriate governmental authorities.

Temporary Line Installation is a Line Installation for electric service of 18 calendar months or less
in duration.

Temporary Service Attachment is a Service Attachment to a customer-provided temporary meter
pole or post which typically furnishes electric service for construction for 18 calendar months or
less in duration.

Terminal Facilities include the transformer and overhead service conductor, or underground
conduit (where applicable). These facilities are not eligible for Vested Interest Refunds.

Underground Service Attachment Charge is the non-refundable charge assessed to an Applicant
or Additional Applicant whenever new underground service is required by a customer attaching
to the Company's distribution system.

Idaho Power Company Original Sheet No. H-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twelfth Revised Sheet No. H-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Unusual Conditions are construction conditions not normally encountered, but which the
Company may encounter during construction which impose additional, project-specific costs.
These conditions may include, but are not limited to: frost, landscape replacement, road
compaction, pavement replacement, chip-sealing, rock digging/trenching, boring, nonstandard
facilities or construction practices, and other than available voltage requirements.

Costs associated with unusual conditions are separately stated and are subject to refund if not
encountered. If unusual conditions are not encountered, the Company will issue the appropriate
refund within 30 days of completion of the project’s reconciliation of costs.

Upgrade is a request by a customer to increase capacity and/or size of Company-owned
distribution facilities. Upgrades are eligible for Vested Interest Refunds.

Vested Interest is the right to a refund that an Applicant or Additional Applicant holds in a specific
section of distribution facilities when Additional Applicants attach to that section of distribution
facilities.

Vested Interest Charge is an amount collected from an Additional Applicant for refund to a Vested
Interest Holder.

Vested Interest Holder is an entity that has paid a refundable Line Installation Charge to the
Company for a Line Installation. A Vested Interest Holder may also be an entity that has paid a
refundable charge to the Company under the provisions of a prior rule or schedule.

Vested Interest Refund is a refund payment to an existing Vested Interest Holder resulting from
a Vested Interest Charge to an Additional Applicant.

Vested Interest Portion is that part of the Company’s distribution system in which a Vested Interest
is held.

Work Order Cost is a cost estimate performed by the Company for a specific request for service
by an Applicant or Additional Applicant. The Work Order Cost will include general overheads of
10.64 percent.

Idaho Power Company Original Sheet No. H-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. H-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
2. General Provisions

a. Cost Information. The Company will provide preliminary cost information addressing the
charges contained in this rule to potential Applicants and/or Additional Applicants. This
preliminary information will not be considered a formal Cost Quote and will not be binding
on the Company or Applicant but rather will assist the Applicant or Additional Applicant in
the decision to request a formal Cost Quote. Upon receiving a request for a formal Cost
Quote, the Applicant or Additional Applicant will be required to provide all necessary
information for a design and pay non-refundable engineering costs to the Company. A
Cost Quote will be binding in accordance with its terms.

b. Ownership. The Company will own all distribution line facilities and retain all rights to them.

c. Rights-of-Way and Easements. The Company will construct, own, operate, and maintain
lines only along public streets, roads, and highways that the Company has the legal right
to occupy, and on public lands and private property across which rights-of-way or
easements satisfactory to the Company will be obtained at the Applicant’s or Additional
Applicant’s expense.

d. Removals. The Company reserves the right to remove any distribution facilities that have
not been used for 1-year. Facilities shall be removed only after providing 60 days’ written
notice to the last customer of record and the owner of the property served.

e. Property Specifications. Applicants or Additional Applicants must provide the Company
with final property specifications as required and approved by the appropriate
governmental authorities. These specifications may include but are not limited to: recorded
plat maps, utility easements, final construction grades, property pins and proof of
ownership.

f. Undeveloped Subdivisions. When electric service is not provided to the individual spaces
or lots within a Subdivision, the Subdivision will be classified as undeveloped.

g. Mobile Home Courts. Owners of mobile home courts with transient tenants, as defined
within Idaho Code § 55-2003(19), will install, own, operate, and maintain all termination
poles, pedestals, meter loops, and conductors from the Point of Delivery.

h. Conditions for Start of Construction. Construction of Line Installations and Alterations will
not be scheduled until the Applicant or Additional Applicant pays the appropriate charges
to the Company.

i. Terms of Payment. All payments listed under this section will be paid to the Company in
cash, a minimum of 30 days and no more than 120 days, prior to the start of Company
construction, unless mutually agreed otherwise.
Idaho Power Company Original Sheet No. H-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. H-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

2. General Provisions (Continued)

j. Interest on Payment. If the Company does not start construction on a Line Installation or
Alteration within 30 days after receipt of the construction payment, the Company will
compute interest on the payment amount beginning on the 31st day and ending once
Company construction actually begins. Interest will be computed at the rate applicable
under the Company's Rule L. If this computation results in a value of $10.00 or more, the
Company will pay such interest to the Applicant, Additional Applicant, or subdivider. An
Applicant, Additional Applicant, or subdivider may request to delay the start of construction
beyond 30 days after receipt of payment in which case the Company will not compute or
pay interest.

k. Fire Protection Facilities. The Company will provide service to Fire Protection Facilities
when the Applicant pays the Work Order Cost for the Line Installation including Terminal
Facilities, less Company Betterment. These costs are not subject to an Allowance, but are
eligible for Vested Interest Refunds under Section 8.a.

l. Customer Provided Trench Digging and Backfill. The Company will, at its discretion, allow
an Applicant, Additional Applicant or subdivider to provide trench digging and backfill. In
a joint trench, backfill must be provided by the Company. Costs of customer-provided
trench and backfill will be removed from or not included in the Cost Quote and will not be
subject to refund.

3. Line Installation Charges

If a Line Installation is required, the Applicant or Additional Applicant will pay a partially refundable
Line Installation Charge equal to the Work Order Cost less applicable Allowances identified in
Section 7.

Idaho Power Company Original Sheet No. H-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. H-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

4. Service Attachment Charges

a. Overhead Service Attachment Charge. If an overhead Service Attachment is required, the
Applicant or Additional Applicant will pay a non-refundable Service Attachment Charge
equal to the Work Order Cost less applicable Allowances identified in Section 7.

b. Underground Service Attachment Charge. Each Applicant or Additional Applicant will pay
a non-refundable Underground Service Attachment Charge for attaching new Terminal
Facilities to the Company's distribution system. The Company will determine the location
and maximum length of service cable.

i. Single Phase 400 Amps or Less and Single Phase Self-Contained Multiple Meter
Bases 500 Amps or Less.

Underground Service Cable (Base charge plus Distance charge)
Base charge from:
underground $ 26.00
overhead including 2" riser $ 965.00
overhead including 3" riser $1,185.00

Distance charge (per foot)
Company Installed Facilities with:
1/0 underground cable $ 14.23
4/0 underground cable $ 14.85
350 underground cable $ 19.30

Customer Provided Trench & Conduit with:
1/0 underground cable $ 3.67
4/0 underground cable $ 4.29
350 underground cable $ 6.16

ii. All Three Phase, Single Phase Greater than 400 Amps, and Single Phase Self-
Contained Multiple Meter Bases Greater Than 500 Amps.

If a three phase, single phase greater than 400 amp, or single phase self-contained
multiple meter base greater than 500 amp underground Service Attachment is
required, the Applicant or Additional Applicant will pay a non-refundable
Underground Service Attachment Charge equal to the Work Order Cost.

Idaho Power Company Original Sheet No. H-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourteenth Revised Sheet No. H-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

5. Vested Interest Charges

Additional Applicants connecting to a vested portion of a Line Installation will pay a Vested Interest
Charge to be refunded to the Vested Interest Holder. Additional applicants will have two payment
options:

Option One - An Additional Applicant may choose to pay an amount determined by this
equation:

Vested Interest Charge = A x B x C where;

A = Load Ratio: Additional Applicant’s Connected Load divided by the sum of
Additional Applicant’s Connected Load and Vested Interest Holder's load.
B = Distance Ratio: Additional Applicant’s distance divided by original distance.
C = Vested Interest Holder’s unrefunded contribution.

Option Two - An Additional Applicant may choose to pay the current Vested Interest, in
which case the Additional Applicant will become the Vested Interest Holder and, as such,
will become eligible to receive Vested Interest Refunds in accordance with Section 8.a.

If Option One is selected, the Additional Applicant has no Vested Interest and the previous Vested
Interest Holder remains the Vested Interest Holder. The Vested Interest Holder's Vested Interest
will be reduced by the newest Additional Applicant's payment.
The Vested Interest Charge will not exceed the sum of the Vested Interests in the Line Installation.
If an Additional Applicant connects to a portion of a vested Line Installation which was established
under a prior rule or schedule, the Vested Interest Charges of the previous rule or schedule apply
to the Additional Applicant.

6. Other Charges

a. Alteration Charges. If an Applicant or Additional Applicant requests a Relocation, Upgrade,
Conversion or removal of Company facilities, the Applicant or Additional Applicant will pay
a non-refundable charge equal to the Cost Quote.

b. Engineering Charge. Applicants or Additional Applicants will be required to prepay all
engineering costs for Line Installations and/or Alterations greater than 16 estimated hours.
Estimates equal to or less than 16 hours will be billed to the Applicant or Additional
Applicant as part of the construction costs, or after the engineering is completed in
instances where construction is not requested. Engineering charges will be calculated at
$87.00 per hour.

Idaho Power Company Original Sheet No. H-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twelfth Revised Sheet No. H-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

c. Engineering Charges for Agencies and Taxing Districts of the State of Idaho. Under the
authority of Idaho Code § 67-2302, an agency or taxing district of the State of Idaho may
invoke its right to decline to pay engineering charges until the engineering services have
been performed and billed to the agency or taxing district. Any state agency or taxing
district that claims it falls within the provisions of Idaho Code § 67-2302 must notify Idaho
Power of such claim at the time Idaho Power requests prepayment of the engineering
charges. Idaho Power may require that the state agency or taxing district’s claim be in
writing. If the state agency or taxing district that has invoked the provisions of Idaho Code
§ 67-2302 does not pay the engineering charges within the 60-day period as provided in
that statute, all the provisions of that statute will apply.

d. Joint Trench Charge. Applicants, Additional Applicants, and subdividers will pay the
Company for trench and backfill costs included in the Cost Quote. In the event the
Company is able to defray any of the trench and backfill costs by sharing a trench with
other utilities, the cost reduction will be included in the Cost Quote.

e. Rights-of-Way and Easement Charge. Applicants or Additional Applicants will be
responsible for any costs associated with the acquisition of rights-of-way or easements.

f. Temporary Line Installation Charge. Applicants or Additional Applicants will pay the
installation and removal costs of providing Temporary Line Installations.

g. Temporary Service Attachment Charge. Applicants or Additional Applicants will pay for
Temporary Service Attachments as follows:

i. Underground - $69.00

The customer-provided meter post must be set within two linear feet of the
Company's existing transformer or junction box.

Idaho Power Company Original Sheet No. H-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twelfth Revised Sheet No. H-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

g. Temporary Service Attachment Charge (Continued)

ii. Overhead - $379.00

The customer-provided meter pole shall be set in a location that does not require
more than 100 feet of #2 aluminum service conductor that can be readily attached
to the permanent location by merely relocating it.

The electrical facilities provided by the customer on the meter pole shall be
properly grounded, electrically safe, meet all clearance requirements, and ready
for connection to Company facilities.

The customer shall obtain all permits required by the applicable state, county, or municipal
governments and will provide copies or verification to the Company as required. The above
conditions must be satisfied before the service will be attached.

h. Temporary Service (Overhead or Underground), Overhead Permanent, and Customer
Provided Trench Inspection Return Trip Charge. A Return Trip Charge of $69.00 will be
assessed each time Company personnel are dispatched to the job site, but are unable to
connect the service. The charge will be billed after the conditions have been satisfied and
the connection has been made.

i. Unusual Conditions Charge. Applicants, Additional Applicants, and subdividers will pay
the Company the additional costs associated with any Unusual Conditions included in the
Cost Quote. This payment, or portion thereof, will be refunded to the extent that the
Unusual Conditions are not encountered.

In the event that the estimate of the Unusual Conditions included in the Cost Quote is equal to or greater
than $10,000, the Applicant, Additional Applicant or subdivider may either pay for the Unusual Conditions
or, at the option of the Company, may furnish an Irrevocable Letter of Credit drawn on a local bank or
local branch office issued in the name of Idaho Power Company for the amount of the Unusual
Conditions. Upon completion of that portion of the project which included an Unusual Conditions estimate,
Idaho Power Company will bill the Applicant, Additional Applicant or subdivider for the amount of Unusual
Conditions encountered up to the amount established in the Irrevocable Letter of Credit. The Applicant,
Additional Applicant or subdivider will have 15 days from the issuance of the Unusual Conditions billing
to make payment. If the Applicant, Additional Applicant or subdivider fails to pay the Unusual Conditions
bill within 15 days, Idaho Power will request payment from the bank.
Idaho Power Company Original Sheet No. H-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. H-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

j. Underground Service Return Trip Charge. When a customer agrees to supply the trench,
backfill, conduit, and compaction for an underground service, an Underground Service
Return Trip Charge of $114.00 will be assessed each time the Company’s installation crew
is dispatched to the job site at the customer’s request, but is unable to complete the cable
installation and energize the service due to the Company’s required specifications not
being met.

7. Line Installation, Shared Terminal Facilities and Service Attachment Allowances

The Company will contribute an Allowance toward the cost of Terminal Facilities associated with
an additional Line Installation and/or Service Attachment. If a Customer increases their
consumptive load and is responsible for upgrading Shared Terminal Facilities, such Customer will
receive an Allowance toward the cost of the upgraded Shared Terminal Facilities. Allowances are
based on the cost of providing and installing Standard Terminal Facilities for single phase and
three phase services.

a. Allowances for Overhead and Underground Line Installations, Shared Terminal Facilities
and Overhead Service Attachments

Class of Service Maximum Allowance per Service

Residential:
Schedules 1, 3, 5, 6 $3,360.00
Non-residence $ 0.00

Non-residential:
Schedules 7, 8, 9, 24
Single Phase $3,360.00
Three Phase $6,890.00

Large Power Service
Schedule 19 Case-By-Case

b. Allowances for Subdivisions and Multiple Occupancy Projects
Developers of Subdivisions and Multiple Occupancy Projects will receive a $3,360.00
Allowance for each single phase transformer installed within a development and a
$6,890.00 Allowance for each three phase transformer installed within a development.
Subdividers will be eligible to receive Allowances for Terminal Facilities installed inside
residential and non-residential subdivisions.

Idaho Power Company Original Sheet No H-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

8. Refunds

a. Vested Interest Refunds. Vested Interest Refunds will be paid by the Company and funded
by the Additional Applicant's Vested Interest Charge as calculated in accordance with
Section 5. The initial Applicant will be eligible to receive refunds up to 80 percent of their
original construction cost. Additional Applicants that become Vested Interest Holders will
be eligible to receive refunds up to their total contribution less 20 percent of the original
construction cost.

A Vested Interest Holder and the Company may agree to waive the Vested Interest
payment requirements of Additional Applicants with loads less than an agreed upon level.
Waived Additional Applicants will not be considered Additional Applicants for purposes of
Section 8.a.i. (1) below.

i. Vested Interest Refund Limitations

(1). Vested Interest Refunds will be funded by no more than 4 Additional
Applicants during the 5-year period following the completion date of the
Line Installation for the initial Applicant.

(2). In no circumstance will refunds exceed 100 percent of the refundable
portion of any party's cash payment to the Company.

b. Subdivision Refunds.

i. Applicants will be eligible for Vested Interest Refunds for facilities installed inside
Subdivisions if the construction was NOT part of the initial Line Installation.
Customers requesting additional Line Installations within a Subdivision will be
considered new Applicants and become eligible for Vested Interest Refunds.

ii. A subdivider will be eligible for Vested Interest Refunds for payments for Line
Installations outside subdivisions.

Idaho Power Company Original Sheet No. H-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

9. Local Improvement Districts

Unless specifically provided for under this paragraph, a Local Improvement District will be
provided service under the general terms of this rule.

The Company will provide a cost estimate and feasibility study for a Local Improvement District
within 120 days after receiving the resolution from the requesting governing body. The Cost Quote
will be based on Work Order Costs and will not be considered binding on the Company if
construction is not commenced within 6 months of the submission of the estimate for reasons not
within the control of the Company. The governing body issuing the resolution will pay the
Company for the costs of preparing the cost estimate and feasibility study regardless of whether
the Line Installation or Alteration actually takes place.

After passage of the Local Improvement District ordinance, the Company will construct the Line
Installation or Alteration. Upon completion of the project, the Company will submit a bill to the
Local Improvement District for the actual cost of the work performed, including the costs of
preparing the cost estimate and feasibility study. If the actual cost is less than the estimated cost,
the Local Improvement District will pay the actual cost. If the actual cost exceeds the estimated
cost, the Local Improvement District will pay only the estimated cost. The governing body will pay
the Company within 30 days after the bill has been submitted.

A Local Improvement District will be eligible for an Allowance for any new load connecting for
service upon the completion of the Line Installation. A Local Improvement District will retain a
Vested Interest in any Line Installation to the Local Improvement District. A Local Improvement
District may waive payments for Vested Interest from Additional Applicants within the Local
Improvement District.

Idaho Power Company Original Sheet No. H-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

10. Relocations in Public Road Rights-of-Way

The Company often locates its distribution facilities within state and local public road rights-of-
way under authority of Idaho Code § 62-705 (for locations outside Idaho city limits) and the
Company’s city franchise agreements (for locations within Idaho city limits). When the Company
is notified of a road improvement project pursuant to Idaho Code § 40-210, the Company will meet
with the Public Road Agency as provided in Idaho Code § 40-210.

If a Public Road Agency determines that the Company’s facilities incommode the public use of
any road, highway, or street, the Public Road Agency can require the company to relocate or
remove the facilities. If a Public Road Agency determines that the Company’s facilities must be
relocated or removed because they incommode the public use of the road, highway, or street, the
Company will relocate its distribution facilities from or within the public road rights-of-way and the
Company will bear the costs of such relocation.

If one or more Private Beneficiaries has requested that the Company’s facilities be relocated or
removed, the Company will use reasonable efforts to recover that portion of the total Relocation
or removal costs attributable to the request from the Private Beneficiaries. If the Private
Beneficiaries dispute the Company’s calculation of the Private Beneficiaries’ cost responsibility,
either the Company or the affected Private Beneficiaries may initiate a proceeding to have the
Commission establish the reasonableness of the Company’s calculation of the Relocation or
removal cost responsibility as between the Company and the Private Beneficiaries.

11. Existing Agreements

This rule shall not cancel existing agreements, including refund provisions, between the Company
and previous Applicants, or Additional Applicants. All Applications will be governed and
administered under the rule or schedule in effect at the time the Application was received and
dated by the Company.

Idaho Power Company Original Sheet No. I-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. I-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS

1. Residential Budget Pay Plan - Schedules 1, 5, and 6. A Budget Pay Plan is available to
Residential Customers desiring to levelize payments for electric service. If a Customer has more than one
electric service on the account, each electric service charge will be levelized individually. A Customer may
sign up for the Budget Pay Plan at any time during the year. In order to be eligible for the Budget Pay
Plan, the Customer’s account must not be in arrears and the customer must have received service at the
same location for a minimum of nine months.

The levelized payment will approximate the average of 12 monthly billings based on either the
historical charges, or an estimate of future charges. The Budget Pay amount for each electric service
on the account will be adjusted to the next higher dollar. Budget Pay amounts will be recalculated at the
12-month (or 365-day) anniversary of the first bill that was generated after the Customer enrolled in the
Budget Pay Plan. The new monthly payment will be the recalculated Budget Pay amount(s). A
Customer’s Budget Pay amount(s) may decrease, increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once
established, the Budget Pay Plan will remain in effect from year to year until the Customer notifies the
Company not less than 30 days prior to the desired date of cancellation or unless the Customer fails to
pay the agreed amounts.

2. Small General Service Budget Pay Plan - Schedules 7 and 8. A Budget Pay Plan is
available to Small General Service Customers receiving service on Schedules 7 and 8. If a Customer has
more than one electric service on the account, each electric service charge will be levelized individually. If
a Customer transfers to another schedule (other than Schedules 1, 5, or 6), the Budget Pay Plan will not
be available. A Customer may sign up for the Budget Pay Plan at any time during the year.

In order to qualify, the Customer must have been receiving service at the same location, under the
same ownership and account number, and with all monthly billings paid on or before the past due date for
at least 12 months prior to applying for the Budget Pay Plan. The Customer must maintain the payment
status as described above or the Customer will be removed from the Budget Pay Plan on the next
monthly billing and all past due balances will become immediately due and payable.
Idaho Power Company Original Sheet No. I-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. I-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS
(Continued)

2. Small General Service Budget Pay Plan - Schedules 7 and 8 (Continued)

The levelized payment will approximate the average of 12 monthly billings based on historical
charges. Budget Pay amounts will be recalculated at the 12-month (or 365-day) anniversary of the first
bill that was generated after the Customer enrolled in the Budget Pay Plan. The Budget Pay amount for
each electric service on the account will be adjusted to the next higher dollar. The new monthly payment
will be the recalculated Budget Pay amount(s). A Customer’s Budget Pay amount(s) may decrease,
increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once established,
the Budget Pay Plan will remain in effect from year to year until the Customer notifies the Company not
less than 30 days prior to the desired date of cancellation or unless the Customer fails to pay the agreed
amounts.

Idaho Power Company Original Sheet No. J-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. J-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

1. Electric Service is inherently subject to occasional interruption, suspension, curtailment,
and fluctuation. The Company designs and operates its system in conformance with the service voltage
ranges described in the current edition of standard C84.1 of the American National Standards Institute –
American National Standard for Electric Power Systems and Equipment – Voltage Ratings (60HZ) and
will have no liability to its Customers or any other persons for any interruption, suspension, curtailment, or
fluctuation in service or for any loss or damage caused thereby if such interruption, suspension,
curtailment, or fluctuation results from any of the following:

a. Causes beyond the Company's reasonable control including, but not limited to,
fire, flood, drought, winds, acts of the elements, court orders, insurrections or riots, generation
failures, lack of sufficient generating capacity, breakdowns of or damage to facilities of the
Company or of third parties, acts of God or public enemy, strikes or other labor disputes, civil,
military or governmental authority, electrical disturbances originating on or transmitted through
electrical systems with which the Company's system is interconnected, and acts or omissions of
third parties;

b. Repair, maintenance, improvement, renewal or replacement work on the
Company's electrical system, which work in the sole judgment of the Company is necessary or
prudent; to the extent practicable work shall be done at such time as will minimize inconvenience
to the Customer and, whenever practicable, the Customer shall be given reasonable notice of
such work;

c. Automatic or manual actions taken by the Company, including, but not limited to,
load curtailment, which in its sole judgment are necessary or prudent to protect the performance,
integrity, reliability or stability of the Company's electrical system or any electrical system with
which it is inter-connected.

2. The provisions of this rule do not affect any person’s rights in tort.

3. Load curtailment and interruption carried out in compliance with an order by governmental
authority shall follow the Company’s plan entitled "Load Curtailment and Interruption Plan", as outlined
below.
Idaho Power Company Original Sheet No. J-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. J-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

LOAD CURTAILMENT AND INTERRUPTION PLAN:

OVERVIEW

1. The Company will comply with all state and federal mandates to curtail the electric
energy used by its Customers to prevent an electrical system collapse. Events that may trigger load
curtailment, either upon notice from state agencies, the Regional Reliability Coordinator, or at the
discretion of the Company, include but are not limited to:

a. Fire, flood, drought, winds, generation failures, lack of sufficient generating capacity,
equipment failures, governmental authority,

b. Actions taken to protect the performance, integrity, reliability or stability of the
Company's electrical system or any electrical system to which it is interconnected, which
actions may occur automatically or manually,

c. Actions taken by the Company that in its sole judgment are necessary or prudent for the
safety of people and/or equipment, or

d. Cyber-attacks or software failure of any part of the Company’s generation, transmission,
and/or distribution system protection and/or control systems.

2. Load curtailment can last for a short amount of time, but also could last for hours or even
days.

AUTOMATIC, REMOTE AND MANUAL ACTIONS

1. Automatic actions occur through the operation of programmed protective equipment
installed on the Company's electrical system, including, without limitation, equipment such as automatic
relays, generator controls, circuit breakers, and switches. This protection equipment is preset to
operate under certain prescribed conditions that, in the sole judgment of the Company, threaten system
performance, integrity, reliability or stability.

2. Where Supervisory Control and Data Acquisition (SCADA) equipment is installed, the
Company will remotely control switches, circuit breakers, relays, voltage regulators or other equipment.
In areas where no SCADA equipment is installed, actions are performed manually by on-site field
personnel.

3. If actions are undertaken, then to the extent permitted by the operating characteristics of
the electrical system, the Company will perform such actions so that interruption, curtailment, or
fluctuation of service to customers will be accomplished sequentially, unless it is necessary in the sole
judgment of the Company, or if required by the Regional Reliability Coordinator to vary said sequence
in order to protect system performance, integrity, reliability or stability.
Idaho Power Company Original Sheet No. J-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. J-3

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

CURTAILMENT AND INTERRUPTION

1. Curtailment and/or interruption of electric service can occur at any time for a multitude of
situations. When these situations arise, Idaho Power intends to take appropriate actions to mitigate the
situation for reliability while maintaining service continuity to as many customers as practical.
Depending on the nature of the situation, mitigation actions will range from actions that will not affect
Customers to actions that curtail and/or interrupt service, impacting localized areas and/or the entire
Idaho Power service area.

2. Idaho Power will promptly notify and keep state regulatory and reliability authorities
informed of the curtailment and/or interruption to electric service.

ROTATING OUTAGES AND ONGOING CURTAILMENT

1. Curtailment and/or interruption of Customer load may be necessary to maintain the
reliability of the electric system in certain situations. In the event Idaho Power must curtail or interrupt
Customer load for any reason, the Company’s intent is to curtail the appropriate amount of load
necessary to mitigate the situation. This is accomplished by selecting the amount or percent of load
reduction needed in the Energy Management System (EMS) Load Shedding application. The EMS
Load Shedding application allows the operator to select the applicable localized area or necessary
portions of the Company’s service area to curtail the load. Load curtailment is accomplished manually
in areas that do not have SCADA connected to the EMS.

2. A range of curtailment stages associated with increasing levels of energy deficiencies
has been developed, incorporating North American Electric Reliability Corporation (NERC) standards.
The circumstances necessitating a reduction in the consumption of electricity in the short term will
normally require that immediate emergency action is taken and as such there may be little or no
warning. Sudden equipment outages or loss of generation could potentially lead directly to any
curtailment stage without prior notice or progression of the stages described below. These stages align
with the severity of the energy deficiency and are intended to minimize customer impact.
Idaho Power Company Original Sheet No. J-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. J-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

ROTATING OUTAGES AND ONGOING CURTAILMENT (Continued)

Stage Nature Type of Curtailment
1 All generation resources are committed.
Firm Customer load, firm transactions,
and reserve commitments are met.
Concerned about sustaining required
Contingency Reserves
 Non-firm wholesale energy sales
 Ask Customers to voluntarily take
conservation measures  
 Issue communications notifying
employees of the situation and asking
Company departments to reduce internal
utility energy use. 
2 Idaho Power is no longer able to
provide expected energy requirements
 Curtailment actions listed in Stage 1
 Interruptible Customer load and available
demand response programs
 Issue communications requesting
government agencies to implement their
programs to achieve necessary energy
reductions
3 Idaho Power is unable to meet minimum
Contingency Reserves as required by
NERC Standards
 Curtailment actions listed in Stage 1 and
Stage 2
 Implement Emergency Load Shed and
Block Rotation
4 Emergency Load Shed due to
immediate risk posed to electrical
reliability.
 Applicable to all Customers. May be
limited to a specific location if reliability risk
is local to an area.

3. Demand response programs, if deployed as a required action under this plan, will not be
operated under the provisions of Schedules 23, 81, and 82. The provisions of Schedules 23, 81, and
82, including but not limited to operating hours, notification requirements, and incentive payments will
not apply for any time period that the Company utilizes a Load Control Device installed under the
programs to interrupt a participating customer’s load for an electric system emergency.

RETURN TO SERVICE

Idaho Power will return service to its Customers when:
 The Company can meet its load and required operating reserves.
 The reliability of the electric system will not be jeopardized.
 Reliability Coordinator approval has been received, if applicable.

Idaho Power Company Original Sheet No. K-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. K-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE K
CUSTOMER'S LOAD AND
OPERATIONS

1. Interference with Service. The Company reserves the right to refuse to supply loads of a
character that may seriously impair service to any other Customers, or may disconnect existing service
if it is seriously impairing service to any other Customers. In the case of pump hoist or elevator motors,
welders, furnaces, compressors, and other installations of like character where the use of electricity is
intermittent, subject to voltage fluctuations, voltage notching or draws a non-sinusoidal (harmonically
distorted) load current, the Company may require the Customer to provide equipment, at the
Customer's expense, to reasonably limit such fluctuations.

2. Practices and Requirements for Harmonic Control. Customers are required to comply
with the Standard for Harmonic Control in Electric Power Systems as set forth in the current Institute of
Electrical and Electronic Engineers (IEEE) Standard 519. The values indicated by IEEE Standard 519
apply at the point where the Company’s equipment interfaces with the Customer’s equipment.

3. Change of Load Characteristic. The Customer shall give the Company prior notice
before making any significant change in either the amount or electrical character of the Customer’s
electrical load thereby allowing the Company to determine if any changes are needed in the Company’s
equipment or distribution system. The Customer may be held liable for damages to the Company’s
equipment resulting from the Customer’s failure to provide said notice of change in electrical load.

4. Protection of Electrical Equipment. The Customer is solely responsible for the selection,
installation, and maintenance of all electrical equipment and wiring (other than the Company's meters
and apparatus) on the load side of the Point of Delivery. The Customer should provide adequate
protection for equipment, data, operations, work and property under the Customer’s control from
system disturbances such as (a) high and low voltage, (b) surges, harmonics, and transients in voltage,
and (c) overcurrent. For unidirectional and three-phase equipment, the Customer should provide
adequate protection from “single phasing conditions”, reversal of phase rotation, and phase unbalance.

5. Motor Installations. The Company reserves the right to refuse single phase service to
motors larger than 7 ½ horsepower.

a. Motor Connection. All motor installations greater than 7 ½ horsepower (HP)
must be approved by the Company to determine how the motor’s connection will affect the
Company’s system. Changes to Company facilities necessary to address the effects of, but not
limited to, flicker, voltage balance, voltage level, or reactive power may be at the Customer’s
expense.

Idaho Power Company Original Sheet No. K-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. K-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE K
CUSTOMER'S LOAD AND
OPERATIONS
(Continued)

5. Motor Installations (Continued)

b. Allowable Motor Starting Currents. The starting currents (as determined by tests
or based on published data by manufacturers) of alternating current motors will not exceed the
allowable locked rotor current values shown in the following table, corrections being allowed to
compensate for the difference between the voltage supply at the motor terminals and its rated
voltage. If the starting current of the motor exceeds the locked rotor current value indicated by
the table below, a starter must be used or other means employed to limit the starting current to
the locked rotor current value specified, except that such starting equipment may be omitted by
written permission of the Company where the absence of such starting equipment will not cause
objectionable voltages. Maximum permissible locked rotor current values in the following table
apply to a single motor installation. Starters may be omitted on the smaller motors of an
installation consisting of more than one motor when their omission will not result in a current in
excess of the allowable locked rotor current of the single largest motor of the group.

llowable Locked Rotor Currents*
Single-Phase Motors Three-Phase Motors
208 Volt 240 Volt 208 Volt 240 Volt 480 Volt Over 480 Volt
Rated Size HP Starting Amps llowed
7.5 127 110
10 163 141 71
15 227 197 99
20 288 250 125
25 351 304 152
30 415 360 180
40 438 380 190
50 462 400 200
60 554 480 240
75 692 600 300
Over 75

*Note: If no value is shown, Company approval of the locked rotor current is required prior to
motor installation.

Idaho Power Company Original Sheet No. L-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. L-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE L
DEPOSITS

1. Residential and Small Commercial Customers. Unless otherwise specified in another rule,
the Company’s practices relating to deposits are governed by the Utility Customer Relations Rules
(UCRRs) of the Idaho Public Utilities Commission, in effect at the time the event occurred which required
application of the UCRRs.

2. Large Commercial and Special Contract Customers. The Company may require a
deposit from Large Commercial or Special Contract Customers as follows:

a. Existing Customers. A deposit may be required for failure to pay the amount due
on or before the date the bill is delinquent, the risk of future loss is evident based on the
Customer’s current commercial credit rating, or the Company becomes aware the Customer’s
business activities are speculative or subject to a high rate of failure. Evidence of a high rate of
failure may include, but is not limited to, elevated risk of bankruptcy.

b. Applicants. A deposit may be required under the following conditions:

i. If the nature of the applicant’s business is speculative or subject to a high
rate of failure; or

ii. The applicant is applying for service with the Company for the first time;
or

iii. The applicant has an outstanding prior service account with the Company
that accrued within the last four years and at the time of application for service remains
unpaid and not in dispute; or

iv. The applicant fails to pass an objective commercial credit screen.

c. Written Explanation for Denial of Service or Requirement of Deposit. If the
Company denies service or requires a cash deposit as a condition of providing or continuing
service, then it will immediately provide a written explanation to the applicant or Customer
stating the reasons why it denies service or requires a deposit. The applicant or Customer will
be given an opportunity to rebut those reasons.

d. Amount of Deposit. The amount of the deposit shall not exceed two times the
Customer’s or applicant’s actual or estimated highest monthly bill. The deposit may be paid in
two equal installments; the first installment must be paid at the time of the application for service
or upon notice from the Company to Existing Customers, and the second installment must be
paid within 30 days.

e. Interest on Deposits. Interest on deposits held by the Company shall be accrued
at the rate established by the Commission specified in IDAPA 31.21.01 Rule 106. Interest shall
be computed from the time the deposit is made until it is refunded or applied to the Customer’s
regular bill. Interest will not accrue on a deposit if service is discontinued temporarily at the
request of a Customer who leaves the deposit with the Company for future use as a deposit, or
if service has been permanently discontinued and the Company has been unsuccessful in its
attempt to refund a deposit.

Idaho Power Company Original Sheet No. L-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. L-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE L
DEPOSITS
(Continued)

2. Large Commercial and Special Contract Customers (Continued)

f. Retention During Dispute. The Company may retain the deposit pending the
resolution of a dispute over termination of service. If the deposit is later returned to the
Customer, the Company shall pay interest at the annual rates established in IDAPA 31.21.01
Rule 106 for the entire period over which the deposit was held.

g. Transfer of Deposit. Deposits shall not be transferred from one Customer to
another Customer or between classes of service, except at the Customer’s request. When a
Customer with a deposit on file transfers service to a new location within the Company’s service
area, the deposit and any outstanding balance shall be transferred to the account for the new
location.

h. Bankrupt Customers. If an applicant for service or a Customer has sought any
form of relief under the Federal Bankruptcy Laws, has been brought within the jurisdiction of the
bankruptcy court for any reason in an involuntary manner, or has had a receiver appointed in a
state court proceeding, then a deposit may be required as a condition of service.

i. Refunding Deposits. The Company may retain deposits for a minimum of twelve
calendar months. If the Customer has established good credit with the Company at the end of
twelve months, or sooner, in the Company’s sole discretion, the original deposit amount along
with any accrued interest will be applied as a credit to the Customer’s current account or
refunded. Whenever a Customer does not establish good credit with the Company at the end of
the first twelve months, the deposit will be retained and the Customer’s credit history will be
evaluated every twelve months until good credit has been established. If a Customer‘s
business activities have been determined to be speculative or subject to a high rate of failure,
the Company may retain the deposit beyond twelve months. In such instances, the need for a
deposit will be evaluated every twelve months until the Customer passes an objective
commercial credit screen.

Idaho Power Company Original Sheet No. M-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. M-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE M
FACILITIES CHARGE SERVICE

This rule applies to eligible customers taking Primary or Transmission Service under Schedules
9, 19 or Special Contract, or Transmission Service under Schedule 24. Eligible Customers may
request that the Company design, install, own, and operate transformers and other facilities beyond the
Point of Delivery that are solely provided to meet the Customer’s service requirements. This service is
provided at the Customer’s request and at the option of the Company in exchange for the Customer
paying a monthly facilities charge to the Company. Primary and Transmission Service level Customers
not taking facilities charge services are responsible for providing the transformation of power beyond
the Point of Delivery needed to meet the Customer’s service requirements. See Rule B.

1. Company-Owned Facilities Beyond the Point of Delivery

Under a facilities charge arrangement, the Company will own and operate facilities beyond the
Point of Delivery that are installed to solely benefit the Customer, and the Customer will pay a
monthly facilities charge to the Company based on a percentage of the total investment cost of
the facilities installed. As part of this arrangement, the Customer agrees to allow Idaho Power
access to the Customer’s property to provide installation of facilities, operation and
maintenance, alteration, relocation, upgrade, conversion, and/or removal in order to meet the
Customer’s service requirements. The Customer agrees to provide rights-of-way as outlined in
Rule C.

Company-owned facilities beyond the Point of Delivery will be set forth in a Distribution Facilities
Investment Report (DFI) provided to the Customer. As the Company’s investment in facilities
beyond the Point of Delivery changes in order to meet the Customer’s service requirements, the
Company shall notify the Customer of the additions and/or deletions of facilities by providing the
Customer a revised DFI. The Company will also adjust the monthly facilities charge to be paid
by the Customer based on any increase or decrease in the investment cost of the Company-
owned facilities resulting from additions and/or deletions as set forth in the revised DFI.

2. Alteration and Failure of Company-Owned Facilities

In the event the Customer requests the Company to alter (remove, reinstall, or change)
Company-owned facilities beyond the Point of Delivery, the Customer shall pay to the Company
the “non-salvable cost” of such removal, reinstallation, or change. Non-salvable cost as used
herein is comprised of the total depreciated costs of materials, labor, and overheads of the
facilities, less the difference between the salvable cost of material removed, and removal labor
cost including appropriate overhead costs.

Failed equipment will be replaced by the Company as part of providing ongoing operation and
maintenance of Company-owned facilities installed beyond the Point of Delivery. When a failed
piece of equipment is replaced by the Company, the initial investment cost of the failed piece of
equipment will be removed from the Customer’s DFI and replaced with the investment cost of
the new piece of equipment to calculate the Customer’s monthly facilities charge.

Idaho Power Company Original Sheet No. M-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. M-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE M
FACILITIES CHARGE SERVICE

3. Sale of Company-Owned Facilities

Customers paying a facilities charge may request to purchase Company-owned facilities
installed beyond the Point of Delivery. All sales of facilities must meet the following provisions:

a. No mixed ownership of facilities. A Customer purchasing Company-owned facilities
installed beyond the Point of Delivery must purchase all facilities listed on the DFI for
that location.

b. The Customer must provide the operation and maintenance of all facilities installed
beyond the Point of Delivery after the sale is complete.

c. The Customer must prepay engineering costs for sales determinations taking greater
than 16 estimated hours of preparation. Sales determinations equal to or less than 16
estimated hours of preparation will be billed to the Customer as part of the sales
agreement, or after the engineering is completed in instances where the sale is not
finalized.

The factors set forth in Idaho Code § 61-328(3) will be considered as a guide for the sale of
Company-owned facilities installed beyond the Point of Delivery to the customer served by
those facilities. All sales shall be brought before the Commission, whether as an application or
other informal procedure.

4. Monthly Facilities Charge Rate

A facilities charge, as specified in Schedule 66, will be assessed on each facilities charge
customer’s monthly billing, regardless of the quantity of energy consumed, until either another
Customer requests to assume responsibility for such facilities charge arrangement, which may
be allowed at the option of the Company, or the facilities charge customer pays to the Company
the non-salvable cost associated with the removal of all Company-owned facilities beyond the
Point of Delivery.

5. Consent and Acknowledge Form

Prior to entering into a facilities charge arrangement, the Customer and Company must agree to
and sign the Facilities Charge Service Consent and Acknowledgement Form attached to this
rule.

Idaho Power Company Original Sheet No. M-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. M-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

RULE M
FACILITIES CHARGE SERVICE

Idaho Power Company
Facilities Charge Service
Consent and Acknowledgement Form

By signing this form, Idaho Power Company (“Idaho Power”) and __________________
(“Customer”) hereby consent to and acknowledge the following:

1. Idaho Power will design, install, own, and operate transformers and other facilities on the
Customer’s property which are beyond Idaho Power’s Point of Delivery and are solely provided to meet
the Customer’s service requirements at the following Customer location:

____________________________________________________________________________

2. This service is provided at the Customer’s request and at the option of Idaho Power in
exchange for the Customer paying a monthly facilities charge to Idaho Power as specified in Schedule
66 of Idaho Power’s current and effective tariff.

3. Idaho Power and the Customer agree that this arrangement is provided under the terms
and conditions of Rule M, Facilities Charge Service, of Idaho Power’s current and effective tariff.

Dated: _____________________

IDAHO POWER COMPANY CUSTOMER

_________________________ _________________________

PRINT NAME PRINT NAME

TITLE TITLE

Idaho Power Company Original Sheet No. 1-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 1-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 1
RESIDENTIAL SERVICE
STANDARD PLAN

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served, and additional investment by the Company for new transmission,
substation or terminal facilities is not necessary to supply the desired service.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate general service schedule
will apply. However, if the wiring is so arranged that the service for residential purposes can be metered
separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

Idaho Power Company Original Sheet No. 1-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighteenth Revised Sheet No. 1-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 1
RESIDENTIAL SERVICE
STANDARD PLAN
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $10.00 $10.00

Energy Charge, per kWh
First 800 kWh 10.1082¢ 8.8958¢
801-2000 kWh 12.1546¢ 9.8073¢
All Additional kWh Over 2000 14.4385¢ 10.8615¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 3-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 3-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 3
MASTER-METERED MOBILE HOME PARK
RESIDENTIAL SERVICE

AVAILABILITY

Service under this schedule is available to master-metered mobile home parks included on the
Company’s list of “grandfathered” mobile home parks on file with the Idaho Public Utilities Commission
receiving electric service under Schedule 1 as of March 20, 2009. Customers included on the Company’s
list of “grandfathered” mobile home parks as of March 20, 2009 will automatically be transferred to this
Schedule on their next regularly scheduled cycle read date that occurs on or after March 21, 2009.

APPLICABILITY

Service under this schedule is applicable to Electric Service provided to a master-metered
residential mobile home park for residential service for general domestic uses, including single phase
motors of 7½ horsepower rating or less. This schedule is not applicable to standby service or shared
service.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit):

Service Charge, per month $10.00

Energy Charge, per kWh
all kWh 10.3844¢

Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Energy Charge, and
the Power Cost Adjustment.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 5-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 5-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF- USE PLAN
(OPTIONAL)

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho to residential Customers where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the Premises to be served, additional investment by the Company for
new transmission, substation or terminal facilities is not necessary to supply the desired service, and
Advanced Meter Reading (AMR) equipment is installed.

The Residential Service Time-of-Use Plan is an optional, voluntary service that provides
residential Customers the option to take electric service with seasonal time-of-use energy rates. If a
Customer requests to participate in this schedule, the Customer will be placed on the schedule effective
with their next billing cycle.

A Customer may terminate their participation on this schedule at any time. However, the
Customer may not subsequently elect service under this schedule for one year after the effective date of
cancellation. If a Customer requests to be taken off of the schedule, the Customer will be removed from
the schedule as of the last meter read date.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate general service schedule
will apply. However, if the wiring is so arranged that the service for residential purposes can be metered
separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.
Idaho Power Company Original Sheet No. 5-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 5-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-USE PLAN
(OPTIONAL)
(Continued)

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season

On-Peak: 7:00 p.m. to 11:00 pm. Monday through Saturday, except holidays
Mid-Peak 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and
holidays

Non-summer Season

On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through Saturday,
except holidays
Off-Peak: 9:00 a.m. to 5:00 p.m. and 8:00 p.m. to 6:00 a.m. Monday through Saturday and
all hours on Sunday and holidays

Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence
Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November),
and Christmas Day (December 25). When New Year’s Day, Independence Day, or Christmas Day falls
on Sunday, the Monday immediately following that Sunday will be considered a holiday.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $10.00 $10.00

Energy Charge, per kWh
On-Peak 24.6472¢ 12.7787¢
Mid-Peak 12.3238¢ n/a
Off-Peak 6.1618¢ 8.5191¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 6-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Residential Service, On-Site Generation is desired, and where additional
investment by the Company for new transmission, substation or terminal facilities is not necessary to
supply the desired service. This service is available to Customers intending to operate Exporting Systems
to generate electricity to reduce all or part of the monthly energy usage.

Standard rates will be applicable unless a Customer elects time-of-use. Time-of-use is an
optional, voluntary service that provides Customers the option to take electric service with seasonal time-
of-use energy rates. If a Customer requests to participate in the optional time-of-use service, the
Customer will be placed on time-of-use under this schedule effective with their next billing cycle.

A Customer may terminate their participation in the time-of-use service at any time. However, the
Customer may not subsequently elect time-of-use service under this schedule for one year after the
effective date of cancellation. If a Customer requests to be taken off of time-of-use service under this
schedule, the Customer will be moved back to the default service under this schedule as of the last meter
read date.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate General Service
Schedule will apply. However, if the wiring is so arranged that the service for residential purposes can
be metered separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

4. Customer owns and/or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System.

5. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

6. Customer meets all applicable requirements detailed in the Company’s Schedule 68,
Interconnections to Customer Distributed Energy Resources.
Idaho Power Company Original Sheet No. 6-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
DEFINITIONS

Designated Meter is the retail meter physically connected to the Exporting System.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer. A Generation Facility is a DER.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.
Idaho Power Company Original Sheet No. 6-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Exporting System; and
Idaho Power Company Original Sheet No. 6-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by
midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer
Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will
carry forward to offset consumption at the Designated Meter until they become eligible for transfer
on January 1 of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
Idaho Power Company Original Sheet No. 6-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the
purpose of installation, operation, maintenance, replacement, or any other service required of said
equipment, as well as all necessary access for inspection, switching, and any other operational
requirements of the Customer’s Interconnections Facilities.

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule
is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers
with permanently removed or disabled systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year. The
non-summer season begins on October 1 of each year and ends on May 31 of each year.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season

On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and
holidays

Non-summer Season

On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through Saturday,
except holidays
Off-Peak: 9:00 a.m. to 5:00 p.m. and 8:00 p.m. to 6:00 a.m. Monday through Saturday and
all hours on Sunday and holidays

Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence
Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November),
and Christmas Day (December 25). When New Year’s Day, Independence Day, or Christmas Day falls
on Sunday, the Monday immediately following that Sunday will be considered a holiday.
Idaho Power Company Original Sheet No. 6-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 6-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County
Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm
Energy Credit).

The following rate structure and charges are subject to change upon Commission approval:

STANDARD RATES (DEFAULT)
Summer Non-summer

Service Charge, per month $10.00 $10.00

Energy Charge, per kWh
First 800 kWh 10.1082¢ 8.8958¢
801-2000 kWh 12.1546¢ 9.8073¢
All Additional kWh Over 2000 14.4385¢ 10.8615¢

TIME-OF-USE RATES (OPTIONAL)

Summer Non-summer

Service Charge, per month $10.00 $10.00

Energy Charge, per kWh
On-Peak 24.6472¢ 12.7787¢
Mid-Peak 12.3238¢ n/a
Off-Peak 6.1618¢ 8.5191¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 7-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 7-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 7
SMALL GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served, and additional investment by the Company for transmission,
substation, or terminal facilities is not necessary to supply the desired service.

APPLICABILITY

Service under this schedule is applicable to Electric Service supplied to a Customer at one Point
of Delivery and measured through one meter. This schedule is applicable to Customers whose metered
energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most
recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under
this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an
actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible
for service under this schedule and will be automatically transferred to the applicable schedule effective
with the next Billing Period. New customers may initially be placed on this schedule based on estimated
usage.

This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo
grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not
applicable to standby service, service for resale, shared service, to individual or multiple family dwellings
first served through one meter after February 9, 1982, or to agricultural irrigation service after October
31, 2004.

TYPE OF SERVICE

The type of service provided under this schedule is single and/or three-phase, at approximately
60 cycles and at the standard service voltage available at the Premises to be served.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

Idaho Power Company Original Sheet No. 7-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventeenth Revised Sheet No. 7-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 7
SMALL GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $25.00 $25.00

Energy Charge, per kWh
First 300 kWh 6.7404¢ 6.7404¢
All Additional kWh 7.7027¢ 6.7421¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 8-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 8-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Small General Service, On-Site Generation is desired, and where
additional investment by the Company for new transmission, substation or terminal facilities is not
necessary to supply the desired service. This service is available to Customers intending to operate
Exporting Systems under this schedule to generate electricity to reduce all or part of their monthly energy
usage.

APPLICABILITY

Effective until a final order is issued that addresses metering configuration for Schedule
84 customers, and any appeal period has passed or the order has been upheld on appeal, existing
Schedule 8 customers who no longer meet the energy usage requirement of Schedule 8 that
‘energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the
most recent 12 consecutive Billing Periods[,]’ can elect Schedule 8.

Service under this schedule is applicable to Electric Service supplied to a Customer at one Point
of Delivery and measured through one meter. This schedule is applicable to Customers whose metered
energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most
recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under
this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an
actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible
for service under this schedule and will be automatically transferred to the applicable schedule effective
with the next Billing Period. New customers may initially be placed on this schedule based on estimated
usage.

This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo
grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not
applicable to standby service, service for resale, shared service, to individual or multiple family dwellings
first served through one meter after February 9, 1982, or to agricultural irrigation service after October
31, 2004.

Service under this schedule is also subject to the following conditions:

1. Customer owns/and or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System.

2. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

3. Customer meets all applicable requirements detailed in the Company’s Schedule 68,
Interconnections to Customer Distributed Energy Resources.
Idaho Power Company Original Sheet No. 8-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

DEFINITIONS

Designated Meter is the retail meter physically connected to the Exporting System.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electricity energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is either delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer. A Generation Facility is a DER.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods, and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

TYPE OF SERVICE

The type of service provided under this schedule is single and/or three-phase alternating current,
at approximately 60 cycles and at the standard service voltage available at the Premises to be served.

Idaho Power Company Original Sheet No. 8-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

Idaho Power Company Original Sheet No. 8-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Exporting System; and

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by midnight,
Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net
Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward
to offset consumption at the Designated Meter until they become eligible for transfer on January 1
of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt, or reduce deliveries of energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
Idaho Power Company Original Sheet No. 8-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 8-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule
is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers
with permanently removed or disabled systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year. The
non-summer season begins on October 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County
Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm
Energy Credit).

The following charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $25.00 $25.00

Energy Charge, per kWh
First 300 kWh 6.7404¢ 6.7404¢
All Additional kWh 7.7027¢ 6.7421¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 9-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No.9-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served and additional investment by the Company for new transmission,
substation, or terminal facilities is not necessary to supply the desired service.

Standard rates will be applicable for Secondary Service unless a Customer elects time-of-use.
Time-of-use is an optional, voluntary service for secondary service that provides secondary service
Customers the option to take electric service with seasonal time-of-use energy rates. If a Customer
requests to participate in the optional time-of-use service, the Customer will be placed on time-of-use
under this schedule effective with their next billing cycle.

A Secondary Service Customer may terminate their participation in the time-of-use service at any
time. However, the Customer may not subsequently elect time-of-use service under this schedule for one
year after the effective date of cancellation. If a Customer requests to be taken off of time-of-use service
under this schedule, the Customer will be moved back to the default service under this schedule as of
the last meter read date.

APPLICABILITY

Service under this schedule is applicable to firm Electric Service supplied to a Customer at one
Point of Delivery and measured through one meter. This schedule is applicable to Customers whose
metered energy usage exceeds 2,000 kWh per Billing Period for a minimum of three Billing Periods during
the most recent 12 consecutive Billing Periods and whose metered Demand per Billing Period has not
equaled or exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods.
This schedule will remain applicable until the Customer’s metered Demand per Billing Period has
exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods. Where the
Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be
prorated to 30 days for purposes of determining eligibility under this schedule. Customers who do not
meet the eligibility requirements for continued service under this schedule will be automatically
transferred to the applicable schedule effective with the next Billing Period. New customers may initially
be placed on this schedule based on estimated usage.

This schedule is not applicable to standby service, service for resale, shared service, to individual
or multiple family dwellings first served through one meter after February 9, 1982, or to agricultural
irrigation service after October 31, 2004.

TYPE OF SERVICE

The type of service provided under this schedule is single-and/or three-phase, at approximately
60 cycles and at the standard service voltage available at the Premises to be served.
Idaho Power Company Original Sheet No. 9-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No.9-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest non-zero monthly Billing Demands
established during the 12-month period which includes and ends with the current Billing Period.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of
maximum use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.
Idaho Power Company Original Sheet No. 9-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No.9-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned,
operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge
to the Company. This service is provided under the provisions set forth in Rule M, Facilities Charge
Service.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

SUMMER AND NON-SUMMER SEASONS

The summer season beings on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.
Idaho Power Company Original Sheet No. 9-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourteenth Revised Sheet No. 9-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the
Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit).

SECONDARY SERVICE – STANDARD RATES Summer Non-summer
(DEFAULT)

Service Charge, per month $25.00 $25.00

Basic Charge, per kW of Basic Load Capacity
Basic Load Capacity $1.48 $1.48

Demand Charge, per kW of Billing Demand
Billing Demand $7.66 $6.04

Energy Charge, per kWh
All kWh 5.1548¢ 4.9718¢

SECONDARY SERVICE – TIME-OF-USE Summer Non-summer
(OPTIONAL)

Service Charge, per month $25.00 $25.00

Basic Charge, per kW of Basic Load Capacity
Basic Load Capacity $1.48 $1.48

Demand Charge, per kW of Billing Demand
Billing Demand $7.66 $6.04

Energy Charge, per kWh
On-Peak 5.5149¢ 5.2572¢
Mid-Peak 5.5149¢ 5.0218¢
Off-Peak 4.9700¢ 4.8345¢

Idaho Power Company Original Sheet No. 9-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventeenth Revised Sheet No. 9-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $340.00 $340.00

Basic Charge, per kW of
Basic Load Capacity $1.73 $1.73

Demand Charge, per kW of
Billing Demand $7.89 $7.48

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.49 n/a

Energy Charge, per kWh
On-Peak 5.0975¢ 4.6295¢
Mid-Peak 5.0975¢ 4.4020¢
Off-Peak 4.5704¢ 4.2196¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $340.00 $340.00

Basic Charge, per kW of
Basic Load Capacity $1.03 $1.03

Demand Charge, per kW of
Billing Demand $6.95 $6.09

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.49 n/a

Energy Charge, per kWh
On-Peak 5.0239¢ 4.5313¢
Mid-Peak 5.0239¢ 4.3036¢
Off-Peak 4.4908¢ 4.1210¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 15-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 15-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 15
DUSK TO DAWN CUSTOMER
LIGHTING

AVAILABILITY

Service under this schedule is available to commercial institutions, industrial plants and
residential Customers presently served from the Company’s interconnected system within the State of
Idaho, where existing overhead secondary distribution facilities of adequate capacity, phase and
voltage are presently available adjacent to the Premises to be lighted.

APPLICABILITY

Service under this schedule is applicable to Electric Service provided for the outdoor dusk to
dawn lighting of commercial, industrial and residential Customer grounds, yards, driveways and
Premises by means of a Company-owned luminary mounted on an existing Company pole with a
support bracket and automatically controlled by a photoelectric relay. At the request of a Customer, but
at the sole discretion of the Company, a luminary may be mounted on a Customer-owned support
acceptable to the Company. The type and kind of fixtures and supports will be in accordance with the
Company’s specifications.

CHARACTER OF SERVICE

The facilities required for supplying service, including the lighting fixture, control relay and
support bracket for mounting on an existing Company pole with secondary service or, at the request of
a Customer and at the Company’s sole discretion, on a Customer-owned support acceptable to the
Company, are supplied, installed, owned and maintained by the Company in accordance with the
Company's standards and specifications. All necessary repairs and maintenance work, including
fixture replacement, will be performed by the Company only during the regularly scheduled working
hours of the Company, and the Company shall be allowed 72 hours following notification by the
Customer for replacing any burned out lighting fixtures. Lighting fixtures are energized each night from
20 minutes after sunset until 20 minutes before sunrise, thereby providing approximately 4,059 hours of
Premises lighting per year. The Company retains the right, but not the obligation, to terminate and
remove service from a Customer-owned support at any time.

If the Customer requests that the Company install a Company-owned lighting fixture on a
Customer-owned support, the Customer, through its request, agrees to permit the Company and its
representatives reasonable access onto and across the Customer’s property for the purposes of
installing, maintaining and removing the lighting fixture. In addition, the Customer voluntarily agrees to
release the Company (including its directors, officers, employees, agents, parent company, affiliates,
successors and assigns) from all liability, loss, claims or actions for injury, death, expenses (including,
but not limited to, reasonable attorney fees and court costs) or damage to person or property resulting
from the Company’s installation, maintenance and removal of the lighting fixture located on a
Customer-owned support. The Customer also agrees to indemnify and hold harmless the Company
from any liability, claim, loss, action or expense (including, but not limited to, reasonable attorney fees
and court costs) asserted against or incurred by the Company for damages arising out of actions or
inactions of the Customer and the Customer’s employees, agents, representatives or others acting on
their behalf.

Idaho Power Company Original Sheet No. 15-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventeenth Revised Sheet No. 15-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 15
DUSK TO DAWN CUSTOMER
LIGHTING
(Continued)

NEW FACILITIES

Where facilities of the Company are not presently available for a lighting fixture installation
which will provide satisfactory lighting service for the Customer's Premises, the Company may install
overhead or underground secondary service facilities, including secondary conductor, poles, anchors,
etc., a distance not to exceed 300 feet to supply the desired service, all in accordance with the charges
specified below.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

1. Monthly Per Unit Charge on existing facilities:
AREA LIGHTING
LED Fixture
Watt (Maximum) Lumen (Minimum) Base Rate
40 3,600 $ 9.45
85 7,200 $11.50
200 18,000 $16.61
FLOOD LIGHTING
LED Fixture
Watt (Maximum) Lumen (Minimum) Base Rate
85 8,100 $18.76
150 18,000 $20.67
300 32,000 $24.31

2. For New Facilities Installed Before June 1, 2004: The Monthly Charge for New Facilities
installed prior to June 1, 2004, will continue to be assessed a monthly facilities charge in accordance
with the changes specified in Schedule 66.

3. For New Facilities Installed On or After June 1, 2004: The non-refundable charge for
New Facilities to be installed, such as underground service, overhead secondary conductor, poles,
anchors, etc., shall be equal to the work order cost.

PAYMENT

The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 19-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 19-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service, those facilities
provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that
additional facilities not provided for under Rule H, including transmission and/or substation facilities, are
required to provide the requested service, special arrangements will be made in a separate agreement
between the Customer and the Company.

APPLICABILITY

Service under this schedule is applicable to and mandatory for Customers who register a metered
Demand of 1,000 kW or more per Billing Period for three or more Billing Periods during the most recent
12 consecutive Billing Periods. Customers whose initial usage, based on information provided by the
Customer, is expected to be 1,000 kW or more per Billing Period for three or more Billing Periods during
12 consecutive Billing Periods may, at the Customer’s request, take service under this schedule prior to
meeting the metered Demand criterion. This schedule will remain applicable until the Customer fails to
register a metered demand of 1,000 kW or more per Billing Period for three or more Billing Periods during
the most recent 12 consecutive Billing Periods.

Deliveries at more than one Point of Delivery or more than one voltage will be separately metered
and billed. If the aggregate power requirement of a Customer who receives service at one or more Points
of Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this
schedule and is required to make special contract arrangements with the Company.

This schedule is not applicable to service for resale, to shared or irrigation service, to standby or
supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or
other standby agreement with the Company, or to multi-family dwellings.

Contract Option. Customers for which this schedule is applicable may optionally take service
under a mutually agreed upon individual special contract between the Customer and the Company
provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special
contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without
change or condition.
TYPE OF SERVICE

The Type of Service provided under this schedule is three-phase at approximately 60 cycles and
at the standard service voltage available at the Premises to be served.

Idaho Power Company Original Sheet No. 19-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On-Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

Idaho Power Company Original Sheet No. 19-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Thirteenth Revised Sheet No. 19-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned,
operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge
to the Company. This service is provided under the provisions set forth in Rule M, Facilities Charge
Service.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

TEMPORARY SUSPENSION

When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic
Load Capacity, the Billing Demand, and the On-Peak Billing Demand shall be prorated based on the
period of such suspension in accordance with Rule G. In the event the Customer's metered demand is
less than 1,000 kW during the period of such suspension, the Basic Load Capacity and Billing Demand
will be set equal to 1,000 kW for purposes of determining the Customer's Monthly Charge.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), and Schedule 96 (Blaine County Surcharge to Fund the
Undergrounding of Certain Facilities).

SECONDARY SERVICE Summer Non-summer

Service Charge, per month $85.00 $85.00

Basic Charge, per kW of
Basic Load Capacity $1.90 $1.90

Demand Charge, per kW of
Billing Demand $9.90 $7.97

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.71 n/a

Energy Charge, per kWh
On-Peak 5.6450¢ 5.1110
Mid-Peak 5.6450¢ 4.8829¢
Off-Peak 5.1197¢ 4.7000¢
Idaho Power Company Original Sheet No. 19-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixteenth Revised Sheet No. 19-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

MONTHLY CHARGE (Continued)

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of $2.09 $2.09
Basic Load Capacity

Demand Charge, per kW of $9.47 $8.14
Billing Demand

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.50 n/a

Energy Charge, per kWh
On-Peak 4.9253¢ 4.4526¢
Mid-Peak 4.9253¢ 4.2244¢
Off-Peak 4.3995¢ 4.0414¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of
Basic Load Capacity $1.76 $1.76

Demand Charge, per kW of
Billing Demand $9.61 $8.27

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.50 n/a

Energy Charge, per kWh
On-Peak 4.9086¢ 4.4239¢
Mid-Peak 4.9086¢ 4.1956¢
Off-Peak 4.3799¢ 4.0125¢

PAYMENT

The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 19-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST

Definitions
Additional Schedule 19 Applicant is a Schedule 19 Customer whose Application requires the
Company to provide new or relocated service from Substation Facilities served by an existing section of
Transmission Facilities with a Transmission Vested Interest.

Applicant is a Schedule 19 Customer whose Application requires the Company to provide new or
relocated service from Substation Facilities served by Transmission Facilities that are free and clear of
any Transmission Vested Interest.

Application is a request by an Applicant or Additional Schedule 19 Applicant for new electric
service from the Company.

Connected Load is the total nameplate MW rating of the electric loads connected for Schedule 19
service.

Distribution Facilities include structures, wires, insulators, and related equipment that are
operated at a 34.5 kilovolt or lower rating.

Substation Allowance is the portion of the cost of the Substation Facilities funded by the Company.

Substation Facilities include those facilities and related equipment that transform the voltage of
energy from a 44 kilovolt or higher rating to a 34.5 kilovolt or lower rating.

Transmission Facilities include structures, wires, insulators, and related equipment that are
operated at a 44 kilovolt or higher rating.

Transmission Line Installation is any installation of new Transmission Facilities owned by the
Company.

Transmission Line Installation Charge is the partially refundable charge assessed an Applicant or
Additional Schedule 19 Applicant whenever a Transmission Line Installation is built for that individual.

Transmission Vested Interest is the right to a refund that an Applicant or Additional Schedule 19
Applicant holds in a specific section of Transmission Facilities when Additional Schedule 19 Applicants
attach to that section of Transmission Facilities.

Transmission Vested Interest Charge is an amount collected from an Additional Schedule 19
Applicant for refund to a Transmission Vested Interest Holder.

Transmission Vested Interest Holder is a person or entity that has paid a refundable Transmission
Line Installation Charge to the Company for a Transmission Line Installation.
Idaho Power Company Original Sheet No. 19-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ninth Revised Sheet No. 19-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST (Continued)

Definitions (Continued)
Transmission Vested Interest Portion is that part of the Company’s transmission system in which
a Transmission Vested Interest is held.

Substation Allowance

If a Schedule 19 Customer’s request for service requires the installation of new or upgraded
transformer capacity in Substation Facilities, the following considerations will be included in the separate
agreement between the Customer and the Company:

The Customer will initially pay for the cost of new or upgraded Substation Facilities
required because of the Customer’s request. The Customer will be eligible to receive a one-time
Substation Allowance based upon subsequent sustained usage of capacity by the Customer.

a. Substation Allowance: The maximum possible allowance will be
determined by multiplying the Customer’s actual increase in load by $79,444 per MW, but
will not exceed the actual cost of the Substation Facilities.

b. Substation Allowance Refunds: The Substation Allowance will be refunded
to the Customer over a five-year period, with annual payments based on the Customer’s
Basic Load Capacity at the time of refund. The first refund will be paid one year following
the first month energy is delivered through the new Substation Facilities.

The refunds will occur based on the following adjustment, which will be
added to the Substation Allowance received in the previous year. If there is no
change in load from the previous year, the Substation Allowance for that year is
equal to the Substation Allowance from the previous year:

((Change in load from the previous year as measured in MW) x (Substation Allowance per MW))
Number of Substation Allowance Refunds remaining in five-year period

The Customer’s annual refunds will be made in accordance with the
Substation Allowance amount stated in the separate construction agreement
between the Customer and the Company.

Transmission Vested Interest

If a Schedule 19 Customer’s request for service requires the installation of new or upgraded
capacity in Transmission Facilities, and those Transmission Facilities are serving the Customer by a
radial feed, the following considerations will be included in the separate agreement between the
Customer and the Company:
Idaho Power Company Original Sheet No. 19-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST (Continued)

Transmission Vested Interest (Continued)

The Customer will initially pay for the cost of new or upgraded Transmission Facilities required
because of the Customer’s request. The Customer may be eligible to receive Transmission Vested
Interest Refunds in accordance with Schedule 19.

Transmission Vested Interest Refunds.
Transmission Vested Interest Refunds will be paid by the Company and funded by the
Additional Schedule 19 Applicant's Transmission Vested Interest Charge as calculated in
accordance with Schedule 19. The initial Applicant will be eligible to receive refunds up to 80
percent of their original construction cost.

Transmission Vested Interest Refund Limitations
a. Transmission Vested Interest Refunds will be funded by no more than 4 Additional
Schedule 19 Applicants during the 5-year period following the completion date of
the Transmission Line Installation.
b. In no circumstance will refunds exceed 100 percent of the refundable portion of
any party's cash payment to the Company.

Transmission Vested Interest Charges:
Additional Schedule 19 Applicants with a Connected Load of greater than 1 MW who
connect to a Transmission Vested Interest Portion of a Transmission Line Installation will pay a
Transmission Vested Interest Charge to be refunded to the Transmission Vested Interest Holder.

An Additional Schedule 19 Applicant will pay an amount determined by this equation:

Transmission Vested Interest Charge = A x B where;

A = Load Ratio: Additional Schedule 19 Applicant’s Connected Load divided by the sum
of Additional Applicant’s Connected Load and Transmission Vested Interest Holder’s
load.
B = Vested Interest Holder’s un-refunded contribution

The Additional Schedule 19 Applicant has no Transmission Vested Interest and the
Transmission Vested Interest Holder remains the Transmission Vested Interest Holder. The
Transmission Vested Interest Holder’s Transmission Vested Interest will be reduced by the
newest Additional Schedule 19 Applicant’s payment.

The Transmission Vested Interest Charge will not exceed the sum of the Transmission Vested
Interests in the Transmission Line Installation. If an Additional Schedule 19 Applicant connects to a
portion of a vested Transmission Line Installation which was established under a prior rule or schedule,
the Transmission Vested Interest Charges of the previous rule or schedule apply to the Additional
Schedule 19 Applicant.
Idaho Power Company Original Sheet No. 20-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service, those facilities
provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that
additional facilities not provided for under Rule H, including transmission and/or substation facilities, are
required to provide the requested service, special arrangements will be made in a separate agreement
between the Customer and the Company.

APPLICABILITY

Service under this schedule is applicable to electric service supplied to a Customer at one Point
of Delivery and measured through one meter delivered at the primary or transmission service level. This
schedule is applicable to Customers whose metered energy usage exceeds 2,000 kWh per Billing Period
for a minimum of three Billing Periods during the most recent 12 consecutive Billing Periods. Where the
Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be
prorated to 30 days for purposes of determining eligibility under this schedule.

Applicable Speculative High-Density Load Large Power Service Rates are mandatory for
Customers who register a metered Demand of 1,000 kW or more per Billing Period for three or more
Billing Periods during the most recent 12 consecutive Billing Periods.

Customers whose metered Demand per Billing Period has not equaled or exceeded 1,000 kW
more than twice during the most recent 12 consecutive Billing Periods will take service under applicable
Speculative High-Density Load Large General Service rates.

At their expense, Customers may request to establish an additional circuit for building systems
independent of the commercial operational load, such as lighting, climate control, among others, at a
separate Point of Delivery. This additional circuit will be separately metered and billed under the
applicable rate schedule. The Customer will be responsible for the costs associated with installing the
second meter. The Company may refuse to provide service at more than one Point of Delivery at the
same Premises if it is determined by the Company that the additional Point of Delivery cannot be provided
without jeopardizing the safety and reliability of the Company's system or service to the Customer or to
other Customers. Service provided to a Customer at multiple Points of Delivery at the same Premises
will not be interconnected electrically.

This schedule is not applicable to service for resale, to shared or irrigation service, to standby or
supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or
other standby agreement with the Company, or to multi-family dwellings.

Idaho Power Company Original Sheet No. 20-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

APPLICABILITY (Continued)

Service under this schedule is applicable to and may be mandatory for Customers who have the
ability to relocate quickly in response to short-term economic signals and meet four or more of the
following criteria:
 High energy use density;
 High load factor;
 Load that is portable and distributable;
 Highly variable load growth or load reduction as an individual customer and/or in aggregate with
similar customers in the Company’s service area;
 High sensitivity to volatile commodity or asset prices;
 Part of an industry with potential to quickly become a large concentration of power demand;
 Lack of credit history or ability to demonstrate financial viability.

If the aggregate power requirement of a Customer who receives service at one or more Points of
Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this
schedule and is required to make special contract arrangements with the Company.

Contract Option. Customers for which this schedule is applicable may optionally take service
under a mutually agreed upon individual special contract between the Customer and the Company
provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special
contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without
change or condition.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Interconnection Facilities are all facilities which are reasonably required by good practices and
the National Electric Safety Code to interconnect the Customer with the capability to remotely interrupt
the load at the Point of Delivery. Such improvements include, but are not limited to, reclosers, load control
devices, and related equipment.

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer with the
capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not
limited to, additional or larger conductors, transformers, poles, and related equipment.

Idaho Power Company Original Sheet No. 20-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

INTERCONNECTION PROCESS

Once a request for new Schedule 20 service is received, Idaho Power will perform a study or
studies to determine what Protection Equipment, Interconnection Facilities, and/or Upgrades are
necessary to interconnect the Customer’s load to Idaho Power’s system. The customer shall pay the
actual costs of all required interconnection studies. Any difference between the deposit (if required) and
the actual cost of the study shall be paid by or refunded to the Customer, as appropriate. If, during the
course of preparing a study, the Company incurs costs in excess of the deposit amount, the Company
may require that the deposit amount be replenished in an amount equal to the estimated costs for
completion of the study. If a deposit amount sufficient to pay for completion of the study is not maintained,
the Company may suspend work on the study.

Idaho Power Company Original Sheet No. 20-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

TYPE OF SERVICE

The Type of Service provided under this schedule is three-phase at approximately 60 cycles
and at the standard service voltage available at the Premises to be served.

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW for Large
Power Service.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On-Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays

The holidays observed by the Company are New Year’s Day, Memorial Day, Independence Day,
Labor Day, Thanksgiving Day, and Christmas Day. When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

Idaho Power Company Original Sheet No. 20-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

FACILITIES BEYOND THE POINT OF DELIVERY

Pursuant to Rule B, customers taking Primary or Transmission Service are responsible for
providing the transformation of power to the voltage at which it is to be used by the Customer.

INTERRUPTION EVENTS

At its discretion, Idaho Power may call Interruption Events to remotely disconnect electric service
to Customer load under the following parameters:

 June 15 through September 15
 1:00 p.m. to 11:00 p.m. Monday through Friday, excluding Holidays
 Maximum ten (10) hours per interruption event
 Up to 225 hours annually

Customer will be notified of upcoming Interruption Event not less than two (2) hours prior to event
start via phone call, or at the Company’s discretion via an alternative mutually-agreed upon method.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

SPECIAL CONDITIONS

The provisions of Interruption do not apply for any time period that the Company requests a load
reduction during a system emergency or any other time that a Customer’s service is interrupted by events
outside the control of the Company.

TEMPORARY SUSPENSION

When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic
Load Capacity and the Billing Demand Shall be prorated based on the period of such suspension in
accordance with Rule G.
Idaho Power Company Original Sheet No. 20-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise
Fees).

Large General Service Rates

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $340.00 $340.00

Basic Charge, per kW of $1.73 $1.73
Basic Load Capacity

Demand Charge, per kW of $8.39 $7.98
Billing Demand

Energy Charge, per kWh
On-Peak 8.8770¢ 6.4611
Mid-Peak 11.5970¢ 8.2028¢
Off-Peak 6.5765¢ 6.9063¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $340.00 $340.00

Basic Charge, per kW of
Basic Load Capacity $1.03 $1.03

Demand Charge, per kW of
Billing Demand $7.45 $6.59

Energy Charge, per kWh
On-Peak 8.8034¢ 6.3629¢
Mid-Peak 11.5234¢ 8.1044¢
Off-Peak 6.4969¢ 6.8077¢

Idaho Power Company Original Sheet No. 20-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

MONTHLY CHARGE (Continued)

Large Power Service Rates

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of $2.09 $2.09
Basic Load Capacity

Demand Charge, per kW of $9.97 $8.64
Billing Demand

Energy Charge, per kWh
On-Peak 8.6996¢ 6.2790¢
Mid-Peak 11.4196¢ 8.0200¢
Off-Peak 6.4004¢ 6.7229¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of
Basic Load Capacity $1.76 $1.76

Demand Charge, per kW of
Billing Demand $10.11 $8.77

Energy Charge, per kWh
On-Peak 8.6829¢ 6.2503¢
Mid-Peak 11.4029¢ 7.9912¢
Off-Peak 6.3808¢ 6.6940¢

PAYMENT

The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 20-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

INTERRUPTION COMPENSATION

Fixed Capacity Reduction Rate:

Large General Service Rates $0.0333 per kilowatt of reduction per event hour

Large Power Service Rates $0.0382 per kilowatt of reduction per event hour

DEFINITIONS

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

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

“Day of” Load Adjustment. The difference between the Original Baseline kW and the actual
metered kW during the hour prior to the Participant receiving notification of an event. Scalar values will
be calculated by dividing the Original Baseline kW for each Interruption Event hour by the Baseline kW
of the hour preceding the event notification time. The scalars are multiplied by the actual event day kW
for the hour preceding the event notification time to create the Adjusted Baseline kW from which load
reduction is measured. The Adjusted Baseline kW for each hour will be capped at 120% of the maximum
kW amount for any hour from the Highest Energy Use Days or the hours during the event day prior to
event notification.

Facility Site(s). All of a Participant’s facility or equipment that is metered from a single service
location that a Participant has taken service under Schedule 20.

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

Interruption Compensation. The Actual kW Reduction for each hour multiplied by the Fixed
Capacity Reduction Rate. Participants are paid based on the average event kilowatt reduction.

Load Control Device. Refers to any technology, device, or system utilized under Schedule 20 to
enable the Company to initiate the Interruption Event.

Interruption Event. Refers to an event where the Company requests or calls for interruption of
specific loads with the use of one or more Load Control Devices.

Original Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days during
the Interruption Event daily parameters, calculated for each Facility Site for each hour.
Idaho Power Company Original Sheet No. 23-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)

PURPOSE

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

AVAILABILITY

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

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

PROGRAM DESCRIPTION

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

DEFINITIONS

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

Idaho Power Company Original Sheet No. 23-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

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

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

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

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

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

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

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

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

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

Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Demand
Credit is calculated by multiplying the Program kW by the demand-related incentive amount for the
Interruption Option selected by the Customer. The Demand Credit will be included on the Customer’s
monthly bills for usage that occurs during the calendar months of June, July, August, and September of
each year. This amount may be prorated for the number of days during the months of June, July, August,
and September that fall in the Customer’s billing cycle to correspond with the Program Season.
Demand Credit = Program kW x demand-related incentive amount
Idaho Power Company Original Sheet No. 23-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

DEFINITIONS (Continued)

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

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

INTERRUPTION OPTIONS

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

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

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

Idaho Power Company Original Sheet No. 23-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

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

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

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

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

Customers participating in the Manual Dispatch Option are required to provide no
less than their Nominated Demand during each Load Control Event. Each time a customer
chooses to provide less than their Nominated Demand during one of the Load Control Events, an
opt-out fee of $6.25 per kW will be assessed on the Nominated Demand not made available for
interruption. The opt-out fee will not exceed the total Bill Credit for the Program Season. Any
opt-out fee will be applied at the end of the Program Season or after the applicable billing cycle
closes. Opt-out fees may be waived for circumstances involving planned or unplanned outages
of 3 hours or more occurring within 24 hours of a Load Control Event or a multiday outage within
72 hours of an event.
Idaho Power Company Original Sheet No. 23-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

INTERRUPTION OPTIONS (Continued)

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

INCENTIVE STRUCTURE

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

INSTALLATION FEES

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

TERM OF AGREEMENT AND TERMINATION

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

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

Demand Credit
($ per Program kW)
Energy Credit
($ per Program kWh)
Energy Credit ($
per Program
kWh) for Out-of-
Demand
Season Billing
Cycles
Standard
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
Extended
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
$5.25 $0.008 $0.021 $0.18 $0.25
Idaho Power Company Original Sheet No. 23-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

TERM OF AGREEMENT AND TERMINATION (Continued)

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

Termination Fees:

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

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

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

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

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

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

SPECIAL CONDITIONS

The provisions of this schedule do not apply for any time period that the Company utilizes a Load
Control Device installed under this Program to interrupt the Customer’s load for a system emergency in
accordance with NERC standards, Idaho Power’s Rule J, or any other time that a Customer’s service is
interrupted by events outside the control of the Company. The provisions of this schedule will not affect
the calculation or rate of the regular Service, Energy or Demand Charges associated with a Customer’s
standard service schedule.
Idaho Power Company Original Sheet No. 23-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 23-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement

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

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

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

NOW, THEREFORE, The Parties agree as follows:

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

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

Idaho Power Company Original Sheet No. 23-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. 23-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

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

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

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

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

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

Idaho Power Company Original Sheet No. 23-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 23-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

7. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s ability to
initiate a Load Control Event at a Metered Service Point(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.

8. The Company’s Schedule 23, any revisions to that schedule and/or any successor schedule are
to be considered part of this Agreement.

9. 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 Idaho Public Utilities
Commission and such other administrative bodies having jurisdiction.

10. Nothing herein shall be construed as limiting the Idaho Public Utilities Commission from changing
any terms, rates, charges, classification of service or any rules, regulations or conditions relating
to service under this Agreement, or construed as affecting the right of the Company or the
Customer to unilaterally make application to the Commission for any such change.

11. In 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.

12. The Company retains the sole right to select and reject the participants to receive service under
Schedule 23. The Company retains the sole right for its employees and its representatives to
install or not install Load Control Devices on the Customer’s electrical panel at the time of
installation depending on, but not limited to, safety, reliability, or other issues that may not be in
the best interest of the Company, its employees or its representatives.

Idaho Power Company Original Sheet No. 23-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 23-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(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.

14. 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)

Idaho Power Company Original Sheet No. 24-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 24-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company’s interconnected system within
the State of Idaho for loads up to 20,000 kW where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the Premises to be served, and additional investment by the Company
for new transmission, substation or terminal facilities is not necessary to supply the desired service. If
the aggregate power requirement of a Customer who receives service at one or more Points of Delivery
on the same Premises exceeds 20,000 kW, special contract arrangements will be required.

APPLICABILITY

Service under this schedule is applicable to power and energy supplied to agricultural use
customers operating water pumping or water delivery systems used to irrigate agricultural crops or
pasturage at one Point of Delivery and through one meter. Water pumping or water delivery systems
include, but are not limited to, irrigation pumps, pivots, fertilizer pumps, drainage pumps, linears, and
wheel lines.

TYPE OF SERVICE

The type of service provided under this schedule is single- and/or three-phase, alternating current,
at approximately 60 cycles and at the standard voltage available at the Premises to be served.

DEFINITIONS

Cumulative Past Due Balance. The Cumulative Past Due Balance is calculated as the sum of all
Schedule 24 past due account balances for which the Customer is financially responsible.

New Irrigation Customer. A New Irrigation Customer is a Customer who, within the previous four
years, has not received Schedule 24 service in the Customer’s name or has received Schedule 24 service
in the Customer’s name for less than three full billing cycles during an Irrigation Season.

Irrigation Season. The Irrigation Season will begin with the Customer's meter reading for the May
Billing Period and end with the Customer's meter reading for the September Billing Period. The beginning
cycles of a Billing Period may actually be based on meter readings taken not more than seven days prior
to the start of the corresponding calendar month.

SERVICE CONNECTION AND DISCONNECTION

The Company will routinely keep service connected throughout the calendar year unless the
Customer requests disconnection. Customer requested service disconnections will be made at no
charge during the Company’s normal business hours. The Company’s termination practices as specified
under Rule F will continue to apply with the exception that service terminations will not be made during
the Irrigation Season.

Idaho Power Company Original Sheet No. 24-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 24-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

SERVICE CONNECTION AND DISCONNECTION (Continued)

Service Connection Charge. A Service Connection Charge as specified in Schedule 66 will be
assessed when service is reconnected.

Service Establishment Charge. A Service Establishment Charge as specified in Schedule 66 will
be assessed when service that is currently energized at the Point of Delivery is established for the
Customer.

Additional Requirements for Connection or Establishment of Service. The Cumulative Past Due
Balance for all of the Customer’s Schedule 24 metered service points must be paid by the Customer
before service will be connected or established. In addition, before service will be provided to a Schedule
24 metered service point, the applicable deposit for that metered service point must be satisfied.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor; PROVIDED That at the Company's
option the Billing Demand of a single motor installation of 5 horsepower and less may be equal to the
number of horsepower but not less than 1 kW. Metered power demands in kW which exceed 130 percent
of the connected horsepower served through one Point of Delivery will not be used for billing purposes
unless and until verified by a field test in the presence of the Customer to be the result of normal pumping
operations. If a demand in excess of 130 percent of the connected horsepower is the result of abnormal
conditions existing on the Company’s interconnected system or the Customer’s system, including
accidental equipment failure or electrical supply interruption which results in the temporary separation of
the Company’s and the Customer’s system, the Billing Demand shall be 130 percent of the connected
horsepower. Customers may appeal the Company’s billing decision to the Commission in cases of
dispute.

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Transmission Service may be owned, operated, and
maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company.
This service is provided under the provisions set forth in Rule M, Facilities Charge Services.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.
Idaho Power Company Original Sheet No. 24-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventeenth Revised Sheet No. 24-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), Schedule 96 (Blain County Surcharge to Fund the
Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit).

SECONDARY SERVICE In-Season Out-of-Season

Service Charge, per month $30.00 $6.00
Demand Charge, per kW of
Billing Demand $14.06 n/a

Energy Charge
All kWh 5.7265¢ 6.7288¢

TRANSMISSION SERVICE In-Season Out-of-Season

Service Charge, per month $415.00 $6.00

Demand Charge, per kW of
Billing Demand $13.27 n/a

Energy Charge
All kWh 5.4849¢ 6.4215¢

Idaho Power Company Original Sheet No. 24-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 24-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

MONTHLY CHARGE (Continued)

Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Demand Charge, the
Energy Charge, the Power Cost Adjustment, and the Facilities Charge.

PAYMENT

All monthly billings for Electric Service supplied hereunder are payable upon receipt, and become
past due 15 days from the date on which rendered. (For any agency or taxing district which has notified
the Company in writing that it falls within the provisions of Idaho Code § 67–2302, the past due date will
reflect the 60-day payment period provided by Idaho Code § 67–2302.)

Deposit. A deposit payment for Schedule 24 Customers is required under the following
conditions:

1. Existing Customers.

a. Tier 1 Deposit. A Tier 1 Deposit will be required from Customers who have
received two or more reminder notices for nonpayment during the most recent 12-month period
during which service was received, have had service terminated for nonpayment during the last
four years and have not subsequently received Schedule 24 service, or were required to pay a
Tier 2 Deposit for the previous Irrigation Season. A Tier 1 Deposit may be satisfied by a guarantee
of payment from a bank or financial institution acceptable to the Company. A reminder notice is
issued approximately 45 days after the bill issue date if the balance owing for Electric Service
totals $100 or more or approximately 105 days after the bill issue date for Customers meeting the
provisions of Idaho Code § 67–2302. A Customer with at least one Schedule 24 account that
meets the requirements for payment of a Tier 1 Deposit will be required to pay a Tier 1 Deposit
on all Schedule 24 accounts for which the Customer is financially responsible and requesting
Schedule 24 service. A Tier 1 Deposit does not apply to Customers who have a Cumulative Past
Due Balance on December 31 equal to or greater than $1,500 (See Tier 2 Deposit). The deposit
for each metered service point is computed as follows:

(1) Monthly Billing Demand is determined by multiplying 80 percent times the
connected horsepower.

(2) Monthly Energy (billing kWh) is determined by multiplying 50 percent times
720 hours times the Monthly Billing Demand.

(3) The Monthly Billing Demand and the Monthly Energy are multiplied by the
current In-Season rates and added to the Irrigation In-Season Service Charge to
determine the estimated monthly bill.

(4) The estimated monthly bill is multiplied by a factor of one and one-half (1.5).
Idaho Power Company Original Sheet No. 24-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 24-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

PAYMENT (Continued)

b. Tier 2 Deposit. Customers with a Cumulative Past Due Balance equal to or greater
than $1,500 on December 31 will be required to pay a Tier 2 Deposit on all Schedule 24 accounts
for which the Customer is financially responsible and requesting Schedule 24 service. A Tier 2
Deposit will also be required from Customers who have had a Cumulative Past Due Balance
equal to or greater than $1,500 on December 31 during any of the previous four years and who
have not subsequently had active Schedule 24 service. A Tier 2 Deposit may be satisfied by a
guarantee of payment from a bank or financial institution acceptable to the Company. The deposit
for each metered service point is computed as follows:

(1) Monthly Billing Demand is determined by multiplying 80 percent times the
connected horsepower.

(2) Monthly Energy (billing kWh) is determined by multiplying 50 percent times
720 hours times the Monthly Billing Demand.

(3) The Monthly Billing Demand and the Monthly Energy are multiplied by the
current In-Season rates and added to the Irrigation In-Season Service Charge to
determine the estimated monthly bill.

(4) The estimated monthly bill is multiplied by a factor of four (4).

2. New Irrigation Customers. A Tier 1 Deposit will be required from a New Irrigation
Customer unless the New Irrigation Customer had a Cumulative Past Due Balance equal to or greater
than $1,500 on December 31 during any of the previous four years and has not subsequently had
Schedule 24 service, in which case a Tier 2 Deposit will be required. The deposit for each metered
service point will be computed using the same methodology as outlined for existing Customers requiring
a Tier 1 or Tier 2 Deposit. A Tier 1 or Tier 2 Deposit for New Irrigation Customers may be satisfied by a
guarantee of payment from a bank or financial institution acceptable to the Company.

3. Bankruptcy or Receivership. An adequate assurance of payment as agreed to by the
Company or as ordered by a court of competent jurisdiction or the Commission shall be required from
any Customer for whom an order for relief has been entered under the federal bankruptcy laws, or for
whom a receiver has been appointed in a court proceeding. As a condition of service, an adequate
assurance of payment equal to a Tier 2 Deposit shall be required. This requirement shall continue from
the date of the order for relief in bankruptcy, or the court appointing a receiver, until the dismissal of the
bankruptcy, or the dismissal of the court proceeding, or until the bankruptcy plan has been completed.

A Customer who has been discharged from bankruptcy, a Customer whose receivership
proceeding has been terminated, or a Customer whose bankruptcy proceedings have been dismissed
will be required to pay an amount equal to a Tier 2 Deposit at the start of the Irrigation Season.

Idaho Power Company Original Sheet No. 24-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 24-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

APPLICATION OF DEPOSIT/INTEREST

Interest will be computed by the Company on irrigation deposits and adequate assurance of
payments required under this schedule at the annual percentage rate determined by the Commission
under Utility Customer Relations Rules 106.02. The irrigation deposit, with accrued interest, will be
applied to the Customer’s account as follows:

Tier 1 Deposits/Interest. All Tier 1 Deposits plus accrued interest will be applied to the
Customer’s account upon date of disconnection or at the time the Customer’s September bill is
prepared, whichever is earlier.

Tier 2 Deposits/Interest. A portion of the Tier 2 Deposit plus accrued interest equal to the
monthly billing amount will be applied to the Customer’s account each month until the Tier 2
Deposit amount plus accrued interest is depleted. Any Tier 2 Deposit amount and/or accrued
interest remaining at the date of service disconnection or at the time of the Customer’s September
billing, whichever is earlier, will be applied to the Customer’s account

Bankruptcy/Interest. Adequate assurance of payments for customers with an active
bankruptcy or court-appointed receivership will be retained by the Company for each active
irrigation account, rather than refunded annually. Prior to each Irrigation Season, the Company
shall request the difference owed to secure an amount equal to a Tier 2 deposit. Any amount and
accrued interest remaining at the date of service disconnection, the date of the order for relief in
bankruptcy, the dismissal date of the bankruptcy, or the dismissal of the court proceeding, will be
refunded or applied to the Customer’s account if a balance exists.

Each irrigation Customer, upon making a deposit payment, will be required to furnish to the
Company an IRS Tax Identification or Social Security number for the Company’s IRS reporting
requirements.

The Company may refuse to accept and retain any deposit that has not been requested or
demanded by the Company. If, however, the Company accepts the deposit that was not requested, the
Company will apply the deposit to the Customer’s account and no interest will be paid.

LATE PAYMENT CHARGE

A Late Payment Charge will be assessed Customers receiving service under this schedule as
provided under Rule G.

Idaho Power Company Original Sheet No. 26-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixteenth Revised Sheet No. 26-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO

SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED MAY 31, 2023

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees). Terms used below have the meanings given to them in the
Special Contract referenced above.

Monthly Contract Demand Charge
$3.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$16.60 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 25,000 kilowatts.

Daily Excess Demand Charge
$1.244 per each kW over the Contract Demand.

Monthly Energy Charge
3.0394¢ per kWh.

Embedded Energy Fixed Cost Charge
0.0000¢ per kWh of Renewable Resource On-Site Usage

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos.1, 2, 3, and Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022,
as amended.

Renewable Resource Cost
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022, as amended.

Excess Generation Credit
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022, as amended.

Administrative Charge
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022, as amended.

Idaho Power Company Original Sheet No. 26-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 26-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO

SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED MAY 31, 2023
(Continued)

RENEWABLE RESOURCE AGREEMENTS

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the tables
below. The Monthly Adjusted Renewable Capacity Credit will be provided to Micron monthly, starting the
month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in Table 3) or the month
following the respective Project’s commercial operation date, whichever is later, and will remain in effect for
the duration of the term of the Renewable Resource PPA or the period of time during which the Idaho
Power-owned Renewable Resource will provide Project Output to Micron, as applicable. The Monthly
Adjusted Renewable Capacity Credit will be provided in accordance with Revised Exhibit 1 of Micron’s
Special Contract, dated March 9, 2022, as amended.

TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit
Rate
$/kW-r
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Black
Mesa
Energy
LLC
2019 40,000 0.3642 14,568 $121.19 1.0 $1,765,495.91
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Black
Mesa
Energy
LLC1
$92,689 $92,689 $308,962 $617,924 $308,962 $79,447 $79,447 $92,689 $92,689

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date
Black Mesa
Ener LLC
2/16/2022 2026 7/1/2026

1Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-22-06, Attachment 1 to Idaho Power Company’s Compliance Filing dated December 23, 2022, as
approved in Order No. 35735 (Apr. 12, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.

Idaho Power Company Original Sheet No. 29-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 29-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 29
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
J. R. SIMPLOT COMPANY
POCATELLO, IDAHO

SPECIAL CONTRACT DATED JUNE 29, 2004

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Contract Demand Charge
$3.11 per kW of Contract Demand

Demand Charge,
$14.23 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW

Daily Excess Demand Charge
$1.244 per each kW over the Contract Demand

Energy Charge
2.9887¢ per kWh

Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.

Idaho Power Company Original Sheet No. 30-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventeenth Revised Sheet No. 30-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 30
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE

SPECIAL CONTRACT DATED SEPTEMBER 15, 2021
CONTRACT NO. 47PA0420D0011

AVAILABILITY

This schedule is available for firm retail service of electric power and energy delivered for the
operations of the Department of Energy's facilities located at the Idaho National Engineering Laboratory
site, as provided in the Contract for Electric Service between the parties.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

1. Demand Charge, per kW of
Billing Demand $9.75

2. Energy Charge, per kWh 4.0951¢

SPECIAL CONDITIONS

1. Billing Demand. The Billing Demand shall be the average kW supplied during the 30-
minute period of maximum use during the month.

2. Power Factor Adjustment. When the Power Factor is less than 95 percent during the 30-
minute period of maximum load for the month, Company may adjust the measured Demand to determine
the Billing Demand by multiplying the measured kW of Demand by 0.95 and dividing by the actual Power
Factor.

MONTHLY ANTELOPE ASSET CHARGE (“AAC”)

The AAC will be paid for the Company’s investment in, and operation and maintenance expenses
associated with, specified transmission facilities required to provide service under the contract.

The Monthly AAC consists of two components:

1. PacifiCorp Pass-Through Charge (PPTC):

PPTC = (O&M x GAV) + (CEC)

Idaho Power Company Original Sheet No. 30-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 30-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 30
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE

SPECIAL CONTRACT DATED SEPTEMBER 15, 2021
CONTRACT NO. 47PA0420D0011
(Continued)

MONTHLY ANTELOPE ASSET CHARGE (“AAC”) (Continued)

2. Idaho Power Ownership Costs (OC):

OC = (ROC x AV) + (PT x AV) + (ROR x NRBA) + (IT x NRBA)

Table 1: Description of AAC Rate Components

Item Description Source
O&M PacifiCorp Operations & Maintenance Expense PacifiCorp OATT1 Formula Rate
GAV Gross Asset Value AV plus original asset value per JOOA2
CEC PacifiCorp Common Equipment Charge PacifiCorp OATT Formula Rate; JOOA Exhibit D
ROC Recovery of Capital Rate Idaho Power OATT Formula Rate
V Joint-Owned Acquisition Value V per JOOA plus utility costs to replace assets
PT Property Taxes Rate Actual Idaho Power Property Tax Data
ROR Rate of Return Current Idaho Power Retail Rate of Return
NRBA Net Rate Base Amount V less accumulated depreciation and ADIT3
IT Income Taxes Rate Idaho Power OATT Formula Rate

The Monthly AAC will reflect the charges detailed in the formulas above according to the most
current values from the data sources listed in Table 1, to be updated annually on October 1, with the exception
of ROR, which will be updated in accordance with its effective date.

1 Open Access Transmission Tariff
2 Joint Ownership and Operating Agreement
3 Accumulated deferred income taxes

Idaho Power Company Original Sheet No. 31-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. 31-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 31
IDAHO POWER COMPANY
AGREEMENT FOR SUPPLY OF
STANDBY ELECTRIC SERVICE
FOR
THE AMALGAMATED SUGAR COMPANY

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Standby Contract Demand Charge, per kW of
Standby Contract Demand $3.11

Standby Facilities Contract Demand Charge
Per kW of Standby Facilities Contract Demand:
Paul Facility: $3.45
Nampa Facility: $3.47
Twin Falls Facility: $3.15

Standby Billing Demand Charge, per kW of
Standby Billing Demand $1.67

Excess Demand Charge
$1.24 per day for each kW taken in excess of the Total Contract Demand.

Energy Charge Energy taken with Standby Demand will be priced at the applicable Schedule 19
Energy Charge.

Idaho Power Company Original Sheet No. 32-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 32-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 32
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
J. R. SIMPLOT COMPANY
CALDWELL, IDAHO

SPECIAL CONTRACT DATED APRIL 8, 2015

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-Summer
Contract Demand Charge
per kW of Contract Demand $3.11 $3.11

Demand Charge
per kW of Billing Demand but no less
than the Contract Demand less 10,000 kW $18.49 $15.28

Daily Excess Demand Charge
per each kW over the Contract Demand $1.244 $1.244

Energy Charge
per kWh 2.8675¢ 3.0975¢

Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.

Idaho Power Company Original Sheet No. 33-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.

SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED AUGUST 3, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor.

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays
Idaho Power Company Original Sheet No. 33-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

TIME PERIODS (Continued)

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day, Thanksgiving Day (fourth Thursday in
November), and Christmas Day (December 25). When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of
Basic Load Capacity $1.76 $1.76

Demand Charge, per kW of
Billing Demand $9.61 $8.27

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.50 n/a

Energy Charge, per kWh
On-Peak 4.9086¢ 4.4239¢
Mid-Peak 4.9086¢ 4.1956¢
Off-Peak 4.3799¢ 4.0125¢

Embedded Energy Fixed Cost Rate, per kWh
On-Peak 0.6951¢ 1.5569¢
Mid-Peak 0.6951¢ 1.5569¢
Off-Peak 0.6951¢ 1.5569¢

Idaho Power Company Original Sheet No. 33-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

BLOCK 2

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).
Terms used below have the meanings given to them in the Special Contract referenced above.

Daily Excess Demand Charge
$1.244 per each kW over the Contract Demand.

Excess Generation Credit
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021 as
amended.

Monthly Contract Demand Charge
$3.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$21.01 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos. 1, 2, 3, and Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated
December 22, 2021, as amended.

Renewable Resource Cost
As included in the Monthly Contract Payment listed in Revised Exhibit 3.1 of Brisbie, LLC’s Special
Contract, December 22, 2021, as amended.

Supplemental Energy Cost
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Administrative Charge
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Idaho Power Company Original Sheet No. 33-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

Renewable Resource Agreements

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project’s commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated December 22, 2021, as amended.

TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit Rate
($/kW-yr)
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Pleasant
Valley
Solar
LLC
2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Pleasant
Valley
Solar LLC1
$416,057 $416,057 $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date
Pleasant
Valley
Solar LLC
10/27/2022 2023 6/1/2023

1 Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42, Attachment 1 to Idaho Power Company’s Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.
Idaho Power Company Original Sheet No. 34-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.

SPECIAL CONTRACT DATED MAY 5, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor. If a Power Factor
adjustment is necessary, the application of the adjustment will be applied to each respective Block at that
Block’s Billing Demand Charge.

Initial Power Factor Adjustment. Effective with the first month’s billing under Schedule 34, and
effective through May 2024 usage, if a Power Factor adjustment is necessary, the application of the 95
percent adjustment will be applied only to the Block 2 Billing Demand. Block 1 Billing Demand will be
subject to a 90 percent Power Factor adjustment during this period.

Block 1 means the first 20,000 kilowatt of the aggregate power requirement at the Lamb Weston Facility.

Block 2 means the aggregate power requirement at the Lamb Weston Facility exceeding the first 20,000
kilowatt.

Block 1 Pricing means the retail rates as defined in Idaho Power Company’s current Idaho retail tariff
Schedule 19 Large Power Service – Primary Service.

Block 1 Energy is the Block 1 Billing Demand multiplied by the Monthly Load Factor multiplied by the
number of hours in the billing month. Block 1 Energy will be subject to the applicable Block 1 Energy
Charge.

Block 2 Energy is the Block 2 Billing Demand multiplied by the Monthly Load Factor multiplied by the
number of hours in the billing month. Block 2 Energy will be subject to the applicable Block 2 Energy
Charge.

Monthly Load Factor is the total aggregate energy consumption at the Lamb Weston facility for the billing
month divided by the number of hours in the billing month divided by the sum of Block 1 and Block 2
Billing Demand.

Idaho Power Company Original Sheet No. 34-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.
Idaho Power Company Original Sheet No. 34-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on September 30 of each year. The
non-summer season begins on October 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $415.00 $415.00

Basic Charge, per kW of
Basic Load Capacity $2.09 $2.09

Demand Charge, per kW of
Billing Demand $9.47 $8.14

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.50 n/a

Energy Charge, per kWh
On-Peak 4.9253¢ 4.4526¢
Mid-Peak 4.9253¢ 4.2244¢
Off-Peak 4.3995¢ 4.0414¢

Idaho Power Company Original Sheet No. 34-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

BLOCK 2

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).

Daily Excess Demand Charge
$1.244 per each kW over the Contract Demand.

Monthly Contract Demand Charge
$3.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$22.85 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Energy Charge
5.8694¢ per kWh of Block 2 Energy.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Idaho Power Company Original Sheet No. 40-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 40-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 40
NON-METERED GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing secondary distribution facilities of adequate capacity, phase and voltage
are available adjacent to the Customer’s Premises and the only investment required by the Company is an
overhead service drop.

APPLICABILITY

Service under this schedule applies to Electric Service for the Customer’s single- or multiple-unit
loads up to 1,800 watts per unit where the size of the load and period of operation are fixed and, as a result,
actual usage can be accurately determined. Service may include, but is not limited to, security lighting,
telephone booths and CATV power supplies which serve line amplifiers. Equipment or loads constructed or
operated in such a way as to allow for the potential or actual variation in energy use are not eligible for
service under this schedule. Facilities to supply service under this schedule shall be installed so that service
cannot be extended to the Customer’s loads served under other schedules. Service under this schedule is
not applicable to shared or temporary service. On or after June 1, 2006, new service under this schedule is
also not applicable to the Customer’s loads on Premises which have metered service.

SPECIAL TERMS AND CONDITIONS

The Customer shall pay for all Company investment, except the overhead service drop, required to
provide service requested by the Customer. The Customer is responsible for installing, owning and
maintaining all equipment, including necessary underground circuitry and related facilities to connect with
the Company's facilities at the Company designated Point of Delivery. If the Customer's equipment is not
properly maintained, service to the specific equipment will be terminated.

Energy used by CATV power supplies which serve line amplifiers will be determined by the power
supply manufacturer's nameplate input rating assuming continuous operation.

The Customer is responsible for notifying the Company of any changes or additions to the
equipment or loads being served under this schedule. Failure to notify the Company of such changes or
additions will result in the termination of service under this schedule and the requirement that service be
provided under one of the Company’s metered service schedules.

If the Customer modifies existing equipment being served under this schedule in a way that allows
for the potential or actual variation in energy usage or installs additional equipment that allows for the
potential or actual variation in energy usage, service under this schedule will be terminated and the
Customer will be required to receive service under one of the Company’s metered service schedules.

With Company approval, municipalities or agencies of federal, state, or county governments may
install equipment that allows for the potential intermittent variation in energy usage at authorized Points of
Delivery. Under these circumstances, the Customer’s bill will include fixed units of the Intermittent Usage
Charge in addition to the Customer’s other Monthly Charges.

The Company is only responsible for supplying energy to the Point of Delivery and, at its expense,
may check energy consumption at any time.
Idaho Power Company Original Sheet No. 40-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 40-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 40
NON-METERED GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The average monthly kWh of energy usage shall be estimated by the Company, based on the
Customer's electric equipment and one-twelfth of the annual hours of operation thereof. Since the
service provided is non-metered, failure of the Customer's equipment will not be reason for a reduction
in the Monthly Charge. The Monthly Charge shall be computed at the following rate, and may also
include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency
Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).

Energy Charge, per kWh 9.377¢

Minimum Charge, per month $2.00

ADDITIONAL CHARGES

Applicable only to municipalities or agencies of federal, state, or county governments with an
authorized Point of Delivery having the potential of intermittent variations in energy usage.

Intermittent Usage Charge, per unit, per month $2.00

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 41-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 41-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho where street lighting wires and fixtures can be installed on Customer-provided street lighting
facilities or installed on the Company's existing distribution facilities.

APPLICABILITY

Service under this schedule is applicable to service requested or installed by Customers for the
lighting of public streets, public alleys, public grounds, and thoroughfares. Street lighting fixtures will be
energized each night from dusk until dawn.

SERVICE LOCATION AND PERIOD

Street lighting facility locations, type of unit and fixture sizes, as changed from time to time by
written request of the Customer and agreed to by the Company, shall be provided for Customers
receiving service under Option A of this schedule. The in-service date for each street lighting facility
shall also be maintained.

The minimum service period for any Company-owned street lighting facility is 10 years. The
Company, upon written notification from the Customer, will remove a Company-owned street lighting
facility:

1. At no cost to the Customer, if such facility has been in service for no less than the
minimum service period. The Company will not grant a request from the Customer for reinstallation of
street lighting service at the same location for a minimum period of two years from the date of removal.

2. Upon payment to the Company of the removal cost, if such facility has been in service
for less than the minimum service period.

SERVICE OPTIONS

"A" - Idaho Power-Owned, Idaho Power-Maintained System.

The facilities required for supplying service, including fixture, lamp, control relay, mast
arm for mounting on an existing utility pole, and energy for the operation thereof, are supplied,
installed, owned and maintained by the Company. All necessary repairs and maintenance
work, including group fixture replacement, will be performed by the Company during the
regularly scheduled working hours of the Company on the Company’s schedule. Individual
fixtures will be replaced on burnout as soon as reasonably possible after notification by the
Customer and subject to the Company's operating schedules and requirements.

The Company has light-emitting diode (“LED”) fixture options. For each initial LED
lighting fixture installation, the Customer is required to state, in writing, a fixture preference. A
maintenance-related replacement of a current LED fixture will be made with a similar type of
fixture as the one being replaced unless written notification has been received from the
Customer requesting a change in fixture types.
Idaho Power Company Original Sheet No. 41-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Tenth Revised Sheet No. 41-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
SERVICE OPTIONS (Continued)

"A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued)

Company-owned lighting systems installed on or after June 1, 2004 shall not be
constructed, operated, or modified in such a way as to allow for the potential or actual variation
in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins.

Company-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service –
Variable Energy Charge until the potential for variations in energy usage has been eliminated.
Repair, modification or alteration of these facilities is not permitted.

Dark Sky Lighting for LED Fixtures

In the event a Customer requests the Company perform an alteration of existing
LED fixtures to become dark sky lighting compliant by adding a lens shield to the
existing fixture, the following charges will apply:

1. The designed cost estimate which includes labor, time, and mileage costs
for the alteration of the existing street lighting fixtures.

2. $27.50 per fixture altered for dark sky lighting.

The total charges identified in 1 and 2 above must be paid prior to the beginning
of the fixture alteration and are non-refundable. The fixture alteration to become dark
sky lighting compliant will be performed by the Company during the regularly scheduled
working hours of the Company and on the Company’s schedule.

LED Shield

In the event a Customer requests the Company install a shield on an LED fixture,
the Customer will be responsible for the material cost of the equipment, as well as the
design cost estimate which includes labor, time, and mileage costs for the alteration of
the existing LED fixture.
Idaho Power Company Original Sheet No. 41-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued)

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees).

Charges, per fixture (41A)

_________________________LED Fixture____________________________
Watt (Maximum) Lumen (Minimum) Base Rate
40 3,600 $11.48
85 7,200 $13.38
140 10,800 $15.34
200 18,000 $19.06

Non-Metered Service – Variable Energy

Energy Charge, per kWh 9.377¢
Pole Charges
For Company-owned poles installed after October 5,1964 required to be
used for street lighting only:
Charge
Wood pole, per pole $1.81
Steel pole, per pole $7.18

Facilities Charges

Customers assessed a monthly facilities charge prior to June 1, 2004 will
continue to be assessed a monthly facilities charge in accordance with the
charges specified in Schedule 66.

Payment

The monthly bill rendered for service supplied hereunder is payable upon receipt
and becomes past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 41-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"C" - Customer-Owned, Customer-Maintained System

The Customer's lighting system, including posts or standards, fixtures, initial installation
of fixtures and underground cables with suitable terminals for connection to the Company's
distribution system, is installed, owned, and maintained by the Customer. The Customer is
responsible for notifying the Company of any changes or additions to the lighting equipment or
loads being served under Option C – Non-Metered Service. Failure to notify the Company of
such changes or additions will result in the termination of non-metered service under Option C
and the requirement that service be provided under Option C - Metered Service.

All new Customer-owned lighting systems installed outside of Subdivisions on or after
January 1, 2012 are required to be metered in order to record actual energy usage.

Customer-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service -
Energy Charge until the street lighting system is converted to Metered Service, or until the
potential for variations in energy usage has been eliminated, whichever is sooner.

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees). For non-metered service, the
average monthly kWh of energy usage shall be estimated by the Company based on the
total wattage of the Customer’s lighting system and 4,059 hours of operation.

Non-Metered Service (41C)

6.339

Idaho Power Company Original Sheet No. 42-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 42-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 42
TRAFFIC CONTROL SIGNAL
LIGHTING SERVICE

APPLICABILITY

Service under this schedule is applicable to Electric Service required for the operation of traffic
control signal lights within the State of Idaho. Traffic control signal lamps are mounted on posts or
standards by means of brackets, mast arms, or cable.

CHARACTER OF SERVICE

The traffic control signal fixtures, including posts or standards, brackets, mast arm, cable,
lamps, control mechanisms, fixtures, service cable, and conduit to the point of, and with suitable
terminals for, connection to the Company's underground or overhead distribution system, are installed,
owned, maintained and operated by the Customer. Service is limited to the supply of energy only for
the operation of traffic control signal lights.

The installation of a meter to record actual energy consumption is required for all new traffic
control signal lighting systems installed on or after June 1, 2004. For traffic control signal lighting
systems installed prior to June 1, 2004 a meter may be installed to record actual usage upon the
mutual consent of the Customer and the Company.

MONTHLY CHARGE

The monthly kWh of energy usage shall be either the amount estimated by the Company based
on the number and size of lamps burning simultaneously in each signal and the average number of
hours per day the signal is operated, or the actual meter reading as applicable. The Monthly Charge
shall be computed at the following rate, and may also include charges as set forth in Schedule 55
(Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for
Municipal Franchise Fees).

Energy Charge, per kWh 7.346¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 45-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 45-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE

AVAILABILITY

Standby Service under this schedule is available at points on the Company's interconnected
system within the State of Idaho where existing facilities of adequate capacity and desired phase and
voltage are available. If additional distribution facilities are required to supply the desired service, those
facilities provided for under Rule H will be provided under the terms and conditions of that rule. To the
extent that additional facilities not provided for under Rule H, including transmission and/or substation
facilities, are required to provide the requested service, special arrangements will be made in a
separate agreement between the Customer and the Company.

Standby Service is available only to Customers taking service under Schedule 9 or Schedule
19.

APPLICABILITY

Service under this schedule is applicable to Customers utilizing on-site generation who request
Standby Service from the Company.

These service provisions are not applicable to service for resale, to service where on-site
generation is used for only emergency supply, or to co-generators or small power producers who have
contracted to supply power and energy.

AGREEMENT

Service shall be provided only after the Uniform Standby Service Agreement is executed by the
Customer and the Company. The term of the Agreement shall be for one year and shall automatically
renew and extend each year, unless terminated under the provisions of the Agreement. The Uniform
Standby Service Agreement will automatically be canceled upon discontinuance of service under
Schedule 9 or Schedule 19.

TYPE OF SERVICE

The Type of Service provided under this schedule is single and/or three-phase at approximately
60 cycles and at the standard voltage available at the Premises to be served.

DEFINITIONS

Supplementary Contract Demand. The firm power contracted for by the Customer under the
Uniform Standby Service Agreement with the Company.

Supplementary Billing Demand. The firm power supplied by the Company on a continuous
basis to supplement the Customer's own generation. Supplementary Billing Demand is equal to the
total average kW supplied during the 15-consecutive-minute period of maximum use during the Billing
Period, adjusted for Power Factor, but not greater than the applicable Supplementary Contract
Demand. Supplementary Billing Demand is billed monthly under the Demand Charge provisions of
Schedule 9 or Schedule 19.

Idaho Power Company Original Sheet No. 45-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 45-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)

DEFINITIONS (Continued)

Standby Contract Demand. The self-generation backup power contracted for by the Customer
under the Uniform Standby Service Agreement.

Standby Billing Demand. The power supplied by the Company to backup the Customer's own
generation. Standby Billing Demand is equal to the total average kW supplied during the 15-
consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor, less
Supplementary Contract Demand, but not less than zero.

Total Contract Demand. The sum of the Supplementary Contract Demand and the Standby
Contract Demand.

Available Standby Capacity. The Total Contract Demand less the Supplementary Billing
Demand and the Standby Billing Demand, but not more than the Standby Contract Demand.

Excess Demand. The total average kW supplied during the 15-consecutive-minute period of
maximum use each day, adjusted for Power Factor, which exceeds the Total Contract Demand by
more than 5 percent.

Total Energy Requirement. The total energy supplied by the Company for supplementary and
standby purposes. The Total Energy Requirement is billed monthly under the applicable Energy
Charge provisions of Schedule 9 or Schedule 19.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing
Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

FACILITIES BEYOND THE POINT OF DELIVERY

Any Company investment in Facilities Beyond the Point of Delivery will be provided under the
terms and conditions of Rule M.

PARALLEL OPERATIONS

Parallel operations will only be authorized by the Company under the terms of the Uniform
Standby Service Agreement with the Customer. At the Company’s discretion, the Company will install
a system protection package at the Customer's expense prior to the start of parallel operations. The
Customer will also pay a Maintenance Charge of 0.61 percent per month times the investment in the
protection package.

Idaho Power Company Original Sheet No. 45-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Revised Sheet No. 45-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)
MONTHLY CHARGE

The Monthly Charge for Standby Service is the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge, if any, at the following rates:

Customers taking service under Schedule 9
Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Secondary Service $5.45 $5.45
Primary Service $5.43 $5.43
Transmission Service $3.11 $3.11

Standby Demand Charge, per kW of
Standby Billing Demand
Secondary Service $9.35 $7.61
Primary Service $9.37 $9.08
Transmission Service $6.95 $6.09

Customers taking service under Schedule 19

Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Primary Service $6.70 $6.70
Transmission Service $3.11 $3.11

Standby Demand Charge, per kW of
Standby Billing Demand
Primary Service $11.69 $10.31
Transmission Service $9.61 $8.27

Customers taking service under Schedule 9 or Schedule 19

Excess Demand Charge
$1.24 per day for each kW taken in excess of the Total Contract Demand.

Minimum Charge
The monthly Minimum Charge shall be the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge.

CONTRIBUTION TOWARD MINIMUM CHARGES ON OTHER SCHEDULES

Any Standby Service Charges paid under this schedule shall not be considered in determining
the Minimum Charge under any other Company schedule.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 45-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 45-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)

IDAHO POWER COMPANY
UNIFORM STANDBY SERVICE
AGREEMENT

ACCOUNT NO. _______________________________

THIS AGREEMENT Made this ___________ day of _________________________________,
20______________ between ________________________________________whose billing address
is _______________________________________________ hereinafter called Customer, and Idaho
Power Company, A corporation with its principal office located at 1221 West Idaho Street, Boise, Idaho,
hereinafter called Company:

NOW, THEREFORE, The parties agree as follows:

1. The Company will agree to provide Standby Service to the Customer's facilities located
at or near_________________________________, County of ___________________________, State
of Idaho, in the form of single and/or three-phase, _______________ volt, Electric Service subject to
emergency operating conditions of the Company.

2. The Supplementary Contract Demand provided by this Agreement is _______________
kW. The Company will provide electric power and energy, to supplement the Customer’s on-site
generation, up to the amount of the stated Supplementary Contract Demand. The Standby Contract
Demand provided by this Agreement is___________________ kW. The Company will provide electric
power and energy, in backup to the Customer's on-site generation, up to the amount of the stated
Standby Contract Demand. The Total Contract Demand provided by this Agreement is
_______________ kW.

3. The availability of power in excess of the Total Contract Demand stated in Paragraph 2
above is not guaranteed and its taking by the Customer may result in a complete or partial curtailment
of service to the Customer. The Company has the right to install, at the Customer's expense, any
device necessary to protect the Company's system from damage which may be caused by the taking of
power in excess of the Standby Contract Demand. The Customer will be responsible for any damages
to the Company's system or damages to third parties resulting from the Customer's taking of power in
excess of the Standby Contract Demand.

4. The terms of this Agreement will not become binding upon the parties until signed by
both parties.

5. At the Company's sole discretion and after receiving written authorization from the
Company, the Customer may operate in parallel with the Company's system. Parallel operations will
be in accordance with the Company's Standards for Interconnection and Parallel operations and the
tariff provisions for Standby Service. Any violation of these provisions will result in the immediate
disconnection of the parallel operation.
Idaho Power Company Original Sheet No. 45-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 45-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)

IDAHO POWER COMPANY
UNIFORM STANDBY SERVICE
AGREEMENT
(Continued)

6. The initial date of service under this Agreement is subject to the Company's ability to
obtain the required labor, materials, equipment, and satisfactory rights-of-way, and to comply with
governmental regulations.

7. The term of this Agreement will be for one year from and after the Initial Service Date
thereof, and will automatically renew and extend each year thereafter unless written notice of
termination is given by either party to the other not less than 12 months prior to the desired termination
date. This Agreement will automatically be canceled upon discontinuance of service under the
Customer’s retail service schedule.

8. The Customer agrees to hold harmless and indemnify the Company, its officers, agents,
and employees, against all loss, damage, expense and liability to third persons or injury to or death of
person or injury to property proximately caused by the Customer's construction, ownership, operation
or maintenance of, or by failure of, any of the Customer's generating facilities.

9. 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, will be subject to valid laws
and to the regulatory authority and orders, rules and regulations of the Idaho Public Utilities
Commission and such other administrative bodies having jurisdiction.

10. Nothing herein will be construed as limiting the Idaho Public Utilities Commission from
changing any rates, charges, classification or service, or any rules, regulation or conditions relating to
service under this Agreement, or construed as affecting the right of the Company or the Customer to
unilaterally make application to the Commission for any such change.

11. The Company's Schedule 45, any revisions to that schedule, and/or any successor
schedule is to be considered as part of this Agreement.

12. In any action at law or equity commenced under this Agreement and upon which
judgment is rendered, the prevailing party, as part of such judgment, will be entitled to recover all costs,
including reasonable attorneys fees, incurred on account of such action.

13. This Agreement replaces and supersedes the Agreement between the parties dated the
_______________ day of ________________________________, 20 ________.

INITIAL SERVICE DATE ______________________________

(APPROPRIATE SIGNATURES)

Idaho Power Company Original Sheet No. 46-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 46-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 46
ALTERNATE DISTRIBUTION
SERVICE

AVAILABILITY

Alternate Distribution Service under this schedule is available at points on the Company's inter-
connected system within the State of Idaho where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the location where Alternate Distribution Service is desired, and where
additional investment by the Company for new distribution facilities is not necessary to supply the
requested service. When additional transmission or substation facilities are required, separate
arrangements will be made between the Customer and the Company.

Alternate Distribution Service is available only to Customers taking Primary Service under
Schedule 9 or 19.

AGREEMENT

Service shall be provided only after the Uniform Alternate Distribution Service Agreement is
executed by the Customer and the Company. The term of the initial agreement shall be dependent upon
the investment required by the Company to provide the Alternate Distribution Service, but shall in no
event be less than one year. The Uniform Alternate Distribution Service Agreement shall automatically
renew and extend each year, unless terminated under the provisions of the Agreement.

TYPE OF SERVICE

Alternate Distribution Service consists of a second distribution circuit to the Customer which
backs up the Customer's regular distribution circuit through an automatic switching device. Alternate
Distribution Service facilities include, but are not limited to, the automatic switching device and that
portion of the distribution substation and the distribution line required to provide the service. The kW of
Alternate Distribution Service capacity shall be specified in the Uniform Alternate Distribution Service
Agreement.

STANDARD OF SERVICE

The Alternate Distribution Service provided under this schedule is not an uninterruptible supply
and is subject to the same standard of service as provided under Rule J.

MONTHLY CHARGES

The Monthly Charge is the sum of the Capacity Charge and the Mileage Charge at the following
rates:

Capacity Charge
$3.59 per contracted kW of capacity

Mileage Charge
$.003 per kW per tenth of a mile in excess of 1.8 miles.
Idaho Power Company Original Sheet No. 46-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 46-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 46
ALTERNATE DISTRIBUTION
SERVICE
(Continued)

MONTHLY CHARGES (Continued)

The distribution line will be measured to the nearest tenth of a mile from the Alternate Distribution
Service substation to the automatic switching device.

FACILITIES CHARGE

The automatic switching device will be owned, operated, and maintained by the Company in
consideration of the Customer paying to the Company a monthly Facilities Charge in accordance with the
charges specified in Schedule 66.

CONTRIBUTION TOWARD MINIMUM CHARGE ON OTHER SCHEDULES

Any alternate Distribution Service charges paid under this schedule shall not be considered in
determining the Minimum Charge under any other Company schedule.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 46-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 46-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
Uniform Alternate Distribution
Service Agreement

LOCATION DESCRIPTION. _______________________ACCOUNT NO.

THIS AGREEMENT between
whose billing address is ____________
hereinafter called Customer, and Idaho Power Company, with its principal office located at 1221 West
Idaho Street, Boise, Idaho, hereinafter called Company:

NOW, THEREFORE, The parties agree as follows:

The Alternate Distribution Service provided through this Agreement consists of a second
distribution circuit to the Customer which backs up the Customer’s regular distribution circuit through an
automatic switching device.

1. This Agreement is subject to the Company’s applicable tariff provisions for Alternate
Distribution Service and is also subject to the Company’s General Rules, Regulations, and Rates as now
or may be hereafter modified and approved by the Idaho Public Utilities Commission.

2. The Company agrees to provide Alternate Distribution Service to the Customer’s loads at
or near , County of , State
of Idaho, in the form of three-phase, volt, Electric Service subject to the emergency
operating conditions of the Company.

3. The Contract Capacity of Alternate Distribution Service provided by this Agreement is
kW. The Company shall reserve this Contract Capacity in the alternate distribution
facilities.

4. The Customer shall pay to the Company a monthly Facilities Charge on the Company’s
investment in the automatic switching device as set forth in the tariff provisions for Alternate Distribution
Service. The amount of this initial investment is set forth in the Distribution Facilities Investment Report
provided by the Company to the Customer. As such investment changes, in order to serve the
Customer’s requirements, the Company shall notify the Customer in writing of additions or deletions of
facilities by forwarding a dated investment notice. The monthly Facilities Charge will be adjusted
accordingly.

5. In the event the Customer requests the Company to remove or reinstall or change the
facilities set forth in the Distribution Facilities Investment Report, the Customer shall pay to the Company
the “non-salvable” cost of such removal, reinstallation or change. Non-salvable cost as used herein is
comprised of the total cost of material, labor, and overheads of installing the facilities, less the difference
between the salvable cost of material removed and the removal labor cost including appropriate overhead
costs.

Idaho Power Company Original Sheet No. 46-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 46-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
Uniform Alternate Distribution
Service Agreement
(Continued)

6. The Company reserves the right to determine the substation and distribution facilities for
both the primary and alternate distribution sources to the Customer for the Contract Capacity specified
under paragraph 3.

7. The initial service date of this Agreement is subject to the Company’s ability to obtain
required labor, materials, equipment, satisfactory rights-of-way, and comply with governmental
regulations.

8. In consideration of the investment required to be made by the Company in the facilities
necessary to provide Alternate Distribution Service, the term of this Agreement shall be for
years from and after the initial service date. The Agreement shall automatically renew and extend each
year thereafter unless written notice of termination is given by either party to the other not less than thirty
(30) days prior to the expiration of the Agreement or any extension of the Agreement. If the Customer
elects not to renew or extend the Agreement, the Customer shall pay the cost of removing the facilities
set forth in the Distribution Facilities Investment Report in accordance with the charges specified under
paragraph 5.

9. This Agreement is subject to valid laws and to the regulatory authority and orders, rules,
and regulations of the Idaho Public Utilities Commission and such other administrative bodies having
jurisdiction.

10. Nothing in this Agreement shall be construed as limiting the Idaho Public Utilities
Commission from changing any rates, charges, classification or service, or any rules, regulation, 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.

Date , 20____.

(APPROPRIATE SIGNATURES)

Idaho Power Company Original Sheet No. 54-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 54-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 54
FIXED COST ADJUSTMENT

APPLICABILITY

This schedule is applicable to the electric energy delivered to all Idaho retail Customers receiving
service under Schedules 1, 3, 4, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General
Service).

Customers added to Idaho Power’s system starting January 1, 2022 will be considered new
customers, all other customers are considered existing customers.

FIXED COST PER CUSTOMER RATE

The Fixed Cost per Customer rate (FCC) is determined by dividing the Company’s fixed cost
components for Residential and Small General Service Customers by the average number of Residential
and Small General Service customers, respectively.

The Fixed Cost per Customer Distribution rate (FCC-Dist) is determined by dividing the
Company’s distribution and customer fixed cost components for Residential and Small General Service
Customers by the average number of Residential and Small General Service Customers, respectively.

Residential FCC FCC-Dist
Schedules 1 and 3 $739.20 $287.96
Schedule 5 $739.20 $287.96
Schedule 6 $654.72 $304.20

Small General Service FCC FCC-Dist
Schedule 7 $174.96 $24.02
Schedule 8 $221.61 $63.33

FIXED COST PER ENERGY RATE

The Fixed Cost per Energy rate (FCE) is determined by dividing the Company’s fixed cost
components for Residential and Small General Service customers by the weather-normalized energy
load for Residential and Small General Service customers, respectively.

The Fixed Cost per Energy Distribution rate (FCE-Dist) is determined by dividing the Company’s
distribution and customer fixed cost components for Residential and Small General Service customers
by the weather-normalized energy load for Residential and Small General Service customers,
respectively.
Idaho Power Company Original Sheet No. 54-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixteenth Revised Sheet No. 54-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 54
FIXED COST ADJUSTMENT
(Continued)

FIXED COST PER ENERGY RATE (Continued)

Residential FCE FCE-Dist
Schedules 1 and 3 6.7098¢ per kWh 2.6138¢ per kWh
Schedule 5 – Summer On-Peak 17.5878¢ per kWh 8.3169¢ per kWh
Schedule 5 – Mid-Peak 8.7941¢ per kWh 4.1586¢ per kWh
Schedule 5 – Summer Off-Peak 4.3970¢ per kWh 2.0792¢ per kWh
Schedule 5 – Non-Summer On-Peak 8.5198¢ per kWh 2.9266¢ per kWh
Schedule 5 – Non-Summer Off-Peak 5.6798¢ per kWh 1.9511¢ per kWh
Schedule 6 7.0780¢ per kWh 3.2886¢ per kWh

Small General Service FCE FCE-Dist
Schedule 7 3.8463¢ per kWh 0.5282¢ per kWh
Schedule 8 5.2308¢ per kWh 1.4949¢ per kWh

ALLOWED FIXED COST RECOVERY AMOUNT

The Allowed Fixed Cost Recovery amount is computed by summing 1) the product of the average
number of existing Residential and Small General Service customers multiplied by the appropriate
Residential and Small General Service FCC rate and 2) the product of the average number of new
Residential and Small General Service customers multiplied by the appropriate Residential and Small
General Service FCC-Dist rate.

ACTUAL FIXED COSTS RECOVERED AMOUNT

The Actual Fixed Costs Recovered amount is computed by summing 1) the product of the actual
energy load for existing Residential and Small General Service customers multiplied by the appropriate
Residential and Small General Service FCE rate and 2) the product of the actual energy load for new
Residential and Small General Service customers multiplied by the appropriate Residential and Small
General Service FCE-Dist rate.

FIXED COST ADJUSTMENT

The Fixed Cost Adjustment (FCA) is the difference between the Allowed Fixed Cost Recovery
Amount and the Actual Fixed Costs Recovered Amount divided by the estimated weather-normalized
energy load for the following year for Residential and Small General Service Customers.

The monthly Fixed Cost Adjustment for Residential Service (Schedules 1, 3, 4, 5, and 6) is 0.4402
cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is
0.5541 cents per kWh.

EXPIRATION

The Fixed Cost Adjustment included on this schedule will expire May 31, 2024.
Idaho Power Company Original Sheet No. 55-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Nineteenth Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT

APPLICABILITY

This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company’s schedules and Special Contracts listed within this schedule. These loads are
referred to as "firm" load for purposes of this schedule.

BASE POWER COST AND PROJECTED POWER COST

The Base Power Cost of the Company's rates, expressed in cents per kWh, is computed by
dividing the sum of the Company's power cost components by firm kWh sales. The power cost
components are segmented into three categories as described in the table below:

The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.

BALANCING ADJUSTMENT

The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment is 0.6357 cents per kWh.

EARNINGS SHARING

Order Nos. 30978, 32424, 33149, and 34071 directed the Company to share a portion of its
earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Company’s 2022 earnings were not above the prescribed threshold resulting in a credit of 0.0000 cents
per kWh.

Idaho Power Company Original Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Thirteenth Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)

POWER COST ADJUSTMENT

The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) the Balancing Adjustment; and 5) Earnings Sharing. The following table calculates
the rates for Categories 1, 2 and 3.

The following table shows the determination of PCA rates for Categories 1, 2, and 3:

Category Description
Base
Power
Cost
Projected
Power
Cost
Difference Sharing
% Rate
(¢ per kWh)
1
The sum of fuel expense and
purchased power expense
(excluding purchases from
cogeneration and small power
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
1.661436 1.991918 0.330482 95% 0.313958
2
Purchased power expense from
cogeneration and small power
producers.
1.369206 1.395299 0.026093 100% 0.026093
3 Demand response incentive
payments. 0.068447 0.073423 0.004976 100% 0.004976
Total 3.099089 3.460640 0.361551 0.345027

Idaho Power Company Original Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twelfth Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)

The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per kWh rates shown below.

Schedule Category
Balancing
djustment
Earnings
Sharing
Total PCA
1 2 3
1 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
3 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
5 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
6 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
7 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
8 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
9S 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
9P 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
9T 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
15 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
19S 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
19P 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
19T 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
24 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
40 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
41 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
42 0.3140 0.0261 0.0050 0.6357 (0.0000) 0.9807
26 0.3140 0.0261 0.0050 0.6357 * 0.9807
29 0.3140 0.0261 0.0050 0.6357 * 0.9807
30 0.3140 0.0261 0.0050 0.6357 * 0.9807
32 0.3140 0.0261 0.0050 0.6357 * 0.9807

* Earnings Sharing Credits are applied as monthly amounts per the table below.

Schedule Special Contract Monthly Credit
26 Micron ($0.00)
29 Simplot ($0.00)
30 DOE ($0.00)
32 Simplot-Caldwell ($0.00)

EXPIRATION

The Power Cost Adjustment included on this schedule will expire May 31, 2024.
Idaho Power Company Original Sheet No. 61-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 61-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 61
PAYMENT FOR HOME WIRING
AUDIT

AVAILABILITY

Service under this schedule is available to residential Customers throughout the Company's
service territory within the State of Idaho who are taking service under Schedules 1, 5, or 6.

SERVICES PROVIDED

A $60 payment is provided by the Company to residential Customers who have a home wiring
audit performed by a licensed electrician. To have a home wiring audit performed, a Customer is
responsible for contacting the Company to request the Home Wiring Audit form and then contacting a
licensed electrician to perform the audit. The Customer is also responsible for ensuring the electrician
performs the audit per the instructions of the Home Wiring Audit form. The charge for the audit will be
established by the electrician and will be billed by the electrician directly to the Customer. The Customer
is responsible for paying the electrician the charge for performing the audit.

The $60 payment is provided to the Customer upon receipt by the Company of the appropriate
copy of the completed Home Wiring Audit form. The Customer is responsible for submitting the Home
Wiring Audit form to the Company.

PURPOSE OF PAYMENT

The purpose of the $60 payment is to assist the Customer in identifying any wiring deficiencies
that may be causing power usage problems. The payment is not an indication that the Company has
performed any analysis as to the safety of the Customer's wiring or that the Company concurs with the
findings of the electrician's wiring audit.

Idaho Power Company Original Sheet No. 62-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 62-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)

PURPOSE

The Clean Energy Your Way Program (the Program) is an optional, voluntary program designed
to provide eligible Customers and non-customer participants an opportunity to participate in the purchase
of environmentally friendly “green” energy. The Program contains two offerings: 1) The Clean Energy
Your Way – Flexible for Customers and non-customers wishing to procure RECs from existing resources
which may or may not be on Idaho Power’s system; and 2) the Clean Energy Your Way – Construction
option for Customers interested in new renewable energy resources.

DEFINITIONS

Excess Generation is calculated on an hourly basis and represents the REF energy delivered to Idaho
Power’s system that exceeds the REF On-Site Usage.

Net Consumption is calculated on an hourly basis and represents the Customer(s) metered kWh usage
less the line loss-adjusted REF energy delivered to Idaho Power’s system. The Net Consumption cannot
be less than zero.

Renewable Construction Agreement will be the contractual agreement developed between Idaho Power
and a Customer(s) governing the terms, conditions, and pricing of a Clean Energy Your Way –
Construction arrangement.

Renewable Energy Certificate (RECs) will be from renewable projects as defined by the Center for
Resource Solutions Green-e Energy standard and renewable energy will be sourced from projects
located in the Western Electricity Coordinating Council’s geographic area of authority with preference
given to projects located in Idaho Power’s service area and the northwest. Renewable energy types will
be primarily wind and solar but may include other certified types such as geothermal, low-impact
hydroelectric, landfill gas, and biomass.

Renewable Energy Facilities (REFs) are resources fueled by solar, wind, biomass, geothermal, or
hydropower. REFs must be located within Idaho Power’s service area or connected to Idaho Power’s
transmission system and represent new facilities (i.e. facilities not previously constructed). A Seller’s
Generation Facility (as defined by Schedule 72) is ineligible to be selected as a REF.

REF Cost will reflect the cost of the resource interconnected to Idaho Power’s system and procured on
behalf of the participating Customer(s).

REF Credit will reflect the benefit of the REF to Idaho Power’s system, subject to Commission approval.

REF On-Site Usage is calculated on an hourly basis and represents the amount of line loss-adjusted
energy generated by the REF up to a Customer(s) metered kWh usage.

Idaho Power Company Original Sheet No. 62-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 62-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 1: CLEAN ENERGY YOUR WAY - FLEXIBLE

APPLICABILITY

For the purpose of the Clean Energy Your Way – Flexible option, renewable energy will be in the
form of RECs. Service under this option is applicable to all Customers and non-customer participants
who choose to participate in the Program.

REC PURCHASE TERMS

Customer participants will designate one of two billing options upon enrollment. Non-customer
participants may only participate under Option 1.

Option 1: Block

Block Size: One Block equals 100 kWh of RECs

Charge Per Block: $1.00 per month

Option 2: Total Usage

Customers may purchase RECs equal to their monthly usage each month at a price
premium of 1.0 cent per billed kWh.

Option 3: Large Purchase Option

For purchases of 750 MWh or more per year, a tailored agreement may be developed
based on individual Customer preference. Pricing and REC composition will be
individually negotiated in a manner that ensures that the full cost of the REC contract is
borne by the participating Customer(s).

BILLING

For a Customer who chooses Option 1, the monthly bill shall be the number of blocks the
Customer has agreed to purchase multiplied by the Charge Per Block. For a Customer who chooses
Option 2, the monthly bill shall be the Customer’s usage, times the price premium per kWh. For a
Customer who chooses Option 3, the bill shall reflect the terms of the tailored agreement. The bill is in
addition to all other charges contained in the Customer’s applicable tariff schedule. A non-customer
participant will be issued an invoice that reflects their designated purchase amount.

PROGRAM ADMINISTRATION

No funds collected from the Clean Energy Your Way – Flexible option may be used for program
administration (program management). A portion of the funds may be used to support program
communications, participant outreach, and marketing.
Idaho Power Company Original Sheet No. 62.-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 62-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 1: CLEAN ENERGY YOUR WAY – FLEXIBLE (Continued)

QUALIFYING INITIATIVES

In an effort to promote local project development and build awareness of renewable energy, if
available, funds collected from the Clean Energy Your Way – Flexible option under REC Options 1 and
2 but not otherwise required to meet program obligations may be distributed to support renewable
demonstration projects at schools located in Idaho Power’s service area. Demonstration projects may
include renewable generation systems, data monitoring, renewable energy curriculum, and teacher
training.

SPECIAL TERMS AND CONDITIONS

Program participants under Options 1 and 2 may apply for, or terminate participation from, the
Clean Energy Your Way – Flexible offering anytime during the year. Participants under Option 3 will be
subject to the terms of the individually negotiated contracts. The Company may limit availability of the
Program subject to available RECs at the cost incurred under the terms described above.

No electric service disconnections will result in the event of non-payment of program
commitments.

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION

APPLICABILITY

Clean Energy Your Way – Construction provides Schedule 19, Large Power Service, and Special
Contract customers an option to buy energy sourced from new renewable projects connected within
Idaho Power’s service area and delivered through Idaho Power’s transmission and distribution system.
This offering is available to individual Customers at a single service point or multiple service points.

Provision of the Construction option is contingent upon Idaho Power and the participating
Customer(s) entering into a Renewable Construction Agreement.

RESOURCE PROCUREMENT

REF procurement will be negotiated by Idaho Power, in consultation with the Customer. REF
characteristics such as generation type and size, construction timing, location, and ownership structure
may vary based on the individual needs of the participating Customer(s) and to ensure non-participating
Customers are held harmless. Customer(s) pursuing the Construction option cannot request to size the
REF greater than 110 percent of the participating service point(s) annual energy amounts. For purposes
of determining annual energy amounts, if available, the most recent 12 months of historical usage will be
used. For new customers, annual energy amounts may be based on a forecast.

The Customer(s) will pay all costs associated with the REF, including but not limited to necessary
studies related to resource acquisition, construction, and integration and interconnection of the resource
with Idaho Power’s system.

Idaho Power Company Original Sheet No. 62-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 62-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION (Continued)

CUSTOMER AGREEMENT AND BILLING STRUCTURE

For each billing period, Customer(s) shall incur or receive the following charges/credits:

1. A participating Customer(s)’ Service Charge, Billing Demand, On-Peak Billing Demand, Basic
Load Capacity, and other monthly charges will be charged at the standard rates, charges, and
fees associated with the Customer’s applicable service schedule;

2. Net Consumption shall be charged at the standard rates, charges, and fees associated with
the Customer’s applicable service schedule;

3. The REF On-Site Usage for Special Contract customers shall be charged at a rate in their
respective service schedule and the REF On-Site Usage for Schedule 19 Customers shall be
charged as follows:

Fixed Cost Component of the Retail Energy Charge, per kWh
Time Period Secondary Service Primary Service Transmission Service
Summer On-Peak 0.6951 ¢ 0.6951 ¢ 0.6951 ¢
Summer Mid-Peak 0.6951 ¢ 0.6951 ¢ 0.6951 ¢
Summer Of -Peak 0.6951 ¢ 0.6951 ¢ 0.6951 ¢
Non-Summer On-Peak 1.5569 ¢ 1.5569 ¢ 1.5569 ¢
Non-Summer Mid-Peak 1.5569 ¢ 1.5569 ¢ 1.5569 ¢
Non-Summer Of -Peak 1.5569 ¢ 1.5569 ¢ 1.5569 ¢

4. Excess Generation shall be credited to the Customer at a rate contained in the Renewable
Construction Agreement;

5. REF Cost as contained in the Renewable Construction Agreement; and,

6. REF Credit as contained in the Renewable Construction Agreement (if applicable).

REC OWNERSHIP AND ADDITIONAL REC PROCUREMENT

REC ownership will be negotiated on an individual Customer basis. A Customer may elect to
take ownership of the REF’s RECs or elect for Idaho Power to retain ownership and retire the RECs on
the Customer’s behalf.

If the REF generation does not meet 100 percent of the Customer(s)’ consumption on a yearly
basis, the Customer(s) may elect to enter into a separate REC purchase contract to cover the difference
between REF generation and the Customer(s)’ consumption. Any separate REC purchase agreement
will be negotiated on a case-by-case basis.

Idaho Power Company Original Sheet No. 62-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 62-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION (Continued)

TERMS AND CONDITIONS

Idaho Power shall have the right to select and reject Program participants at its sole discretion
based on criteria Idaho Power considers necessary to ensure the effective operation of the Program.

The terms and term length of the Renewable Construction Agreement will be determined in a
negotiation between Idaho Power and the Customer(s). The Renewable Construction Agreement will be
subject to Commission approval.

The REF generation cannot be used to offset a Customer(s)’ Basic Load Capacity, Billing Demand
or On-Peak Billing Demand.

The Renewable Construction Agreement must include a Customer(s) financial guarantee to cover
stranded REF costs in the event of Customer default, dissolution, and/or relocation. The guarantee
amount will be negotiated between the Customer(s) and Idaho Power based on the value of the REF to
ensure stranded costs are not shifted to non-participants.

Idaho Power Company Original Sheet No. 66-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 66-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES

PURPOSE

The purpose of this schedule is to accumulate all miscellaneous charges that are included in the
Company’s Rules, Regulations, and Rates.

APPLICABILITY

This schedule applies to all Customers taking service under the Company’s Idaho Tariff except
as expressly limited by a rule or a schedule.

CHARGES

RULE D

1. Instrument Transformer Metering

Current transformer

Single phase – AMI metering $451.00

Polyphase – AMI metering $898.00

2. Special Meter Tests Requested by the Customer $85.00

RULE F (all times are stated in Mountain Time)

1. Service Establishment Charge $30.00

2. Continuous Service Reversion Charge $15.00

3. Field Visit Charge
Schedules 1, 3, 5, 6, 7, 8, 9 $25.00
Schedules 15, 19, 20, 24, 40, 41, 42 $45.00

4. Service Connection Charge
Schedules 1, 3, 5, 6, 7, 8, 9
Monday through Friday
7:30 am to 6:00 pm $30.00
6:01 pm to 9:00 pm $70.00
9:01 pm to 7:29 am $120.00

Company Holidays and Weekends
7:30 am to 9:00 pm $70.00
9:01 pm to 7:29 am $120.00

Idaho Power Company Original Sheet No. 66-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 66-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

RULE F (all times are stated in Mountain Time) (Continued)

Schedules 15, 19, 20, 24, 40, 41, 42
Monday through Friday
7:30 am to 6:00 pm $50.00
6:01 pm to 9:00 pm $95.00
9:01 pm to 7:29 am $175.00

Company Holidays and Weekends
7:30 am to 9:00 pm $95.00
9:01 pm to 7:29 am $175.00

Remote Service Connection
All schedules, all days, all times $8.50

The following is a list of Company-recognized holidays and the dates they are observed: New Year’s
Day (January 1), Martin Luther King Jr. Day (third Monday in January), President’s Day (third Monday
in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday
in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25).
When a holiday falls on Saturday, the previous Friday will be observed. When a holiday falls on a
Sunday, the following Monday will be observed.

RULE G

1. Returned Check Charge $20.00
2. Late Payment Charge 12 percent per annum, or
one percent per month.
3. Fractional Period Minimum Billings
Schedules 1, 3, 5, 6, 7, and 8 $3.00
Schedules 9 and 19 Secondary Service Level $3.00
Schedules 9, 19 and 20 Primary and Transmission
Service Levels $50.00
Schedule 24 $3.00
Schedule 40 $2.00

Idaho Power Company Original Sheet No. 66-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. 66-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

RULE M

1. Monthly Facilities Charge Rate

Facilities Installed Facilities Installed
31 Years or Less More Than 31 Years
Schedule 9 1.34% 0.61%
Schedule 15 1.62% 1.62%
Schedule 19 1.34% 0.61%
Schedule 24 1.34% 0.61%
Schedule 29 1.34% 0.61%
Schedule 32 1.34% 0.61%
Schedule 41 1.13% 1.13%
Schedule 45 1.34% 0.61%
Schedule 46 1.34% 0.61%

The monthly Facilities Charge is determined by multiplying the Monthly Facilities Charge
Rate by the Company’s total investment in distribution facilities installed beyond the
Point of Delivery.

Idaho Power Company Original Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho to all Customer Generators owning or operating DERs, in Parallel with the Company’s system,
that qualify for Schedule 6, Schedule 8, Schedule 84, or Non-Export as defined in this schedule. Non-
Exporting Systems with Total Nameplate Capacity of 3 MVA or greater are required to sign a Uniform
Customer Generator Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to construction, operation, and maintenance of a Customer
Generator System interconnected in Parallel with the Company’s system. In limited circumstances,
certain interconnection requirements included in this schedule may not be applicable when the Company
determines the DER relies on a technology, such as regenerative drives, that does not jeopardize grid
stability or reliability. In making its determination, the Company will evaluate criteria such as the
magnitude and duration of exports.

DEFINITIONS

Company is the Idaho Power Company.

Company-Furnished Facilities are those portions of the Interconnection Facilities funded by the
Customer Generator and provided by the Company.

Customer Generator is a Customer applying to operate or operating a DER in Parallel with the
Company’s system.

Customer Generator-Furnished Facilities are those portions of the Interconnection Facilities
provided by the Customer Generator.

Customer Generator Interconnection Process is the Company’s DER interconnection application,
engineering review, construction, and inspection process for Customer Generator Systems. The
Customer Generator Interconnection Process intends to ensure a safe and reliable generation
interconnection in compliance with all applicable regulatory requirements, good utility practices, and
national safety standards.

Customer Generator System is an Exporting System or a Non-Exporting System.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s
system, including enclosures or other equipment as may be required to ensure that only the Company
will have access to the devices.

Idaho Power Company Original Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company.

Feasibility Review is the Company’s standard engineering review of a proposed Customer
Generator System and is intended to ensure the Company’s system is equipped to incorporate the
proposed Customer Generator-Furnished Facilities in a manner that conforms with good utility practices
and the National Electric Safety Code.

Feasibility Study is the Company’s more detailed engineering assessment for DERs as
determined by the Feasibility Review. This study is intended to ensure that the Company’s system is
sufficiently equipped to incorporate proposed DERs in a manner that conforms with good utility practices
and the National Electric Safety Code, including protection coordination and system voltage
management.

Generation Facility means equipment used to produce electric energy at a specific physical
location and service point that qualifies for Schedules 6, 8, 84, or Non-Export. A Generation Facility is a
DER.

Inadvertent Export is the unplanned, unscheduled, and uncompensated transfer of electrical
energy from a Customer’s Non-Exporting System to the Company’s system across the Interconnection
Point.

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Idaho Power Company Original Sheet No. 68-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Non-Exporting System is a Customer-owned DER that limits or prevents electrical energy from
transferring to the Company’s system.

Parallel connection means operating a DER that is connected to and receives voltage from Idaho
Power’s system.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles, or equipment.

Smart Inverter is an inverter that conforms to the latest IEEE 1547 standards and is certified by
the UL 1741 standard, which complies with the latest IEEE 1547 standards.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the
Customer’s DER to the Company’s system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of the Customer Generator System as described in this schedule.

Total Nameplate Capacity is the total of the gross capacity of a DER as designated by the
manufacturer(s) maximum continuous operating rating of the DER in Alternating Current (AC), or as
determined by Idaho Power based on information provided on the System Verification Form.

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Idaho Power Company Original Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Customer Generators requesting interconnection to the
Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Customer Generator-Furnished Interconnection Facilities will be constructed and maintained
in a manner as determined by the Company to be in full compliance with all good utility practices, National
Electric Safety Code, conforms to the IEEE 1547 standards, and all other applicable federal, state, and
local safety and electrical codes and standards at all times.

The Customer Generator shall:

1. Upon request, submit proof to the Company that all licenses, permits, inspections, and
approvals necessary for the construction and operation of the Customer’s DER and Interconnection
Facilities under this schedule have been obtained from applicable federal, state, or local authorities.

2. Upon request, submit the designs, plans, specifications, and performance data for the
DER and Customer Generator-Furnished Facilities to the Company for review. The Company’s
acceptance shall not be construed as confirming or endorsing the design, or as a warranty of safety,
durability, or reliability of the DER or Customer Generator-Furnished Facilities. The Company will retain
the right to inspect this equipment at its discretion.

3. Demonstrate to the Company’s satisfaction that the Customer’s DER and Customer
Generator-Furnished Facilities have been completed, and that all features and equipment of the
Customer’s DER and Customer Generator-Furnished Facilities are capable of operating safely to
commence deliveries of energy into the Company’s system.

4. Provide and maintain adequate Protection Equipment sufficient to prevent damage to the
DER, Customer Generator-Furnished Facilities, and any other Customer Generator-owned facilities in
conformance with all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical
and safety codes and requirements as described within this Schedule.

6. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
best effort to arrange repairs and inspections during normal business hours and to notify the Customer
Generator of such arrangements in advance. The Company will provide a telephone number to the
Customer Generator so that the Customer Generator can obtain information about Company activity
impacting the Customer’s DER.

Idaho Power Company Original Sheet No. 68-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Customer DERs. The Disconnection Equipment shall
be installed at an electrical location to allow complete isolation of Customer’s DER and Interconnection
Facilities from the Company’s system. Disconnection Equipment will be installed at an electrical location
on the Customer Generator’s side of the Company’s retail metering point to allow complete isolation of
the Customer’s DER and Interconnection Facilities from the Customer Generator’s other electrical load
and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed and visible within 10 feet of the Interconnection Point or permanently-
posted instructions at the Interconnection Point indicating the exact location of the Disconnection
Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

5. Equipped with a visual disconnect that enables the Company to visually confirm that the
Customer’s and Company’s conductors are physically disconnected. This requires the ability to inspect
the actual conductors visually. Circuit breakers do not satisfy this requirement.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
DER and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior notice
will be provided. In the event of planned repairs, the Company will attempt to notify the Customer
Generator of the time and duration of the planned outage.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event that
any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the
Customer’s Generation Facility are deemed by the Company to be in default or delinquent.
Idaho Power Company Original Sheet No. 68-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

Customer Generators will be subject to disconnection and reconnection charges if the expenses
are incurred as the result of a DER and/or a Customer’s failure to abide by the provisions of Schedule
68.

Disconnection of the service may be necessary. The disconnection may result in the interruption
of both energy deliveries from the Customer Generator System to the Company as well as the interruption
of energy deliveries from the Company to the Customer Generator. Disconnection provisions specific to
Customer Generator Systems less than 3 MVA are described further in Section 2 of this tariff.
Disconnection provisions specific to Non-Exporting Systems greater than 3 MVA are described further in
Section 4 of this tariff.

The Company will establish the settings of Protection Equipment to disconnect the Customer’s
DER and Interconnection Facilities for the protection of the Company’s system and personnel consistent
with good utility practices. If the Customer Generator attempts to modify, adjust or otherwise interfere
with the Protection Equipment or its settings as established by the Company, such action may be grounds
for the Company’s refusal to continue interconnection of the Customer’s DER and Interconnection
Facilities to the Company’s system.

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications, and test results of the Customer Generator-Furnished Facilities to the Company for review
upon request by the Company. Upon receipt of the design and equipment specifications, the Company
will review the design and equipment specifications for conformance with applicable electrical and safety
codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense.

Idaho Power Company Original Sheet No. 68-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

INVERTER REQUIREMENTS

Iinverter-based Customer Generator Systems must use a Smart Inverter programmed with the
required settings described in the following section. System Modifications that (1) do not replace or add
inverters, (2) are the result of warranty inverter replacements, or (3) rely on an inverter that is required to
meet the original inverter specifications for the Customer Generator System to properly function, may be
considered exempt from this requirement.

INVERTER SETTINGS

All inverter-based Customer Generator System Smart Inverters will be set for normal operating
performance Category B as defined in IEEE 1547, with the default reactive power control mode set for
the Voltage-reactive power mode and the parameters listed in Table 1. All inverter-based Customer
Generator System Smart Inverters will be set for abnormal voltage and ride through operating
performance Category III as defined in IEEE 1547 using the default settings. The remaining Smart
Inverter settings will be set to the default values specified in IEEE 1547.

Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS
Voltage-reactive power parameters Default Settings
V1 0.92 per unit of nominal voltage
Q1 44% of nameplate apparent power rating, injecting
V2 0.98 per unit of nominal voltage
Q2 0
V3 1.03 per unit of nominal voltage
Q3 0
V4 1.06 per unit of nominal voltage
Q4 44% of nameplate apparent power rating, absorption
Open-loop response time 5 seconds

ENERGY STORAGE DEVICE

Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or
Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that
are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export
energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows:

1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility,
the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC
coupled system can be an Exporting or Non-Exporting system.
Idaho Power Company Original Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

ENERGY STORAGE DEVICE (Continued)

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.

APPLICATION EXPIRATION

Applications that are not completed within one year of the initial Feasibility Review are considered
expired. Customers requesting connection or approval of expired applications are required to resubmit
a completed application form and $100 application fee and are subject to the full application process
described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.

SYSTEM MODIFICATIONS

1. Any modifications to Customer Generator Systems that increase the Total Nameplate Capacity
of the system or modify the system in any way (including inverter replacements) that may impact the
safety or reliability of the Company’s electrical system are considered system modifications for the
purposes of this tariff.

Idaho Power Company Original Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

2. Customer Generators planning to make system modifications must submit an application,
$100 fee, and complete the application process according to the procedures required for new
interconnection.

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.

b. Option 2: Permanently disable the DER from Parallel operations with the
Company system. Permanent disablement of the DER requires an inspection to be scheduled
with the Company within twelve (12) months from the postmarked notification date. Customers
that do not schedule within this time period will be subject to termination of service.

Idaho Power Company Original Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

The following section is applicable to all Customer Generators with Total Nameplate Capacity
less than 3 MVA.

APPLICATION PROCESS

Customers requesting to interconnect a DER less than 3 MVA are required to complete the
following application process prior to interconnection:

1. Customers must submit a completed application form and a $100 application fee to the
Company. Applications are available on the Company’s website or will be provided to the Customer
upon request.

2. Upon receipt of a completed application and $100 fee, the Company will either (1) provide
the Customer with a written or electronic notification that the application has been received and all
necessary information has been provided, or (2) request the Customer provide forms of documentation
outlined in Section 1.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on project information provided in the
application. The Feasibility Review determines the capability of the Company’s electrical system to
incorporate the proposed Customer Generator System and determines if Upgrades are necessary.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed” notification.

Idaho Power Company Original Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will perform the Feasibility Study within 15 business days. If the results of the Feasibility Study
indicate that Upgrades or Protection Equipment are necessary to accommodate the proposed project,
the Company will notify the Customer of such Upgrades or Protection Equipment.

a. Installation and funding of the construction, installation, and maintenance of
required Protection Equipment will be subject to the following provisions:

i. Protection Equipment Requirements (Rotating Machines): Generation
Facilities up to 500 kVA Total Nameplate Capacity may not require additional Protection
Equipment but will be evaluated on a case-by-case basis. Generation Facilities greater
than 500 kVA Total Nameplate Capacity will require additional Company-Furnished
Protection Equipment.

ii. Protection Equipment Requirements (Other DER): DER up to 3 MVA Total
Nameplate Capacity may not require additional Protection Equipment but will be evaluated
on a case-by-case basis.

iii. When it is determined Company-owned Protection Equipment is required,
the Customer shall pay the actual costs of all required Protection Equipment prior to the
start of Parallel operations. The Customer will also pay a Maintenance Charge of 0.59
percent per month times the investment in the Protection Equipment.

Idaho Power Company Original Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

5. Following receipt of “Approval to Proceed,” the Customer is responsible for completing the
installation of the Customer Generator System and fulfilling all applicable federal, state, and local
inspection requirements. Customers must also provide the Company with a completed System
Verification Form detailing the specifications of all installed components of the completed Customer
Generator System. System Verification Forms can be found on the Company’s website or will be
provided upon request. Upon completion, the Company reserves the right to request the Customer to
provide forms of documentation outlined in Section 1, verifying that all federal, state, and local
requirements have been met.

6. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, local, and Customer Generation Interconnection Process requirements have
been met, the Company will complete, barring conditions beyond the Company’s control, an on-site
inspection within ten (10) business days for DER with Total Nameplate Capacity of 100 kVA or less and
within twenty (20) business days for DER with Total Nameplate Capacity of greater than 100 kVA.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements. The Company on-site inspection may include the following:

a. Verification that actual installed components correspond to the information
provided on the initial application and the System Verification Form.
b. Verification that the disconnect is functional and reconnection time complies with
IEEE 1547.
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect.
d. Photographic documentation of the installation.
e. Posting of appropriate Company signage.
f. Documentation of the meter number and system configuration.
g. Verification of Smart Inverters.
h. Verification of Total Nameplate Capacity.

7. A return trip charge of $52.00 will be billed to the Customer each time Company personnel
are dispatched to the job site but are unable to conduct the on-site inspection due to one or more of the
conditions not being met that had been certified as complete by the Customer or installer on the System
Verification Form.

8. Successful completion of the Company on-site inspection constitutes the conclusion of the
application process. The Company must make a reasonable effort to move an Exporting Customer
Generator to the appropriate rate schedule within five (5) business days. Under no circumstances will
the rate change occur more than fifteen (15) business days from the date of the successfully completed
inspection. Upon completion of this process, the Customer will receive confirmation that the application
process has been successfully completed.

Idaho Power Company Original Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS

APPLICATION PROCESS (Continued)

9. It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving notice from the Customer indicating Customer’s Generation System meets all
applicable federal, state, and local requirements and is suitable for connection.

In addition to the requirements of Section 1, the following section is applicable to all Customer
Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedule 1 or Schedule 7 that own and/or operate a
Generation Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA or less,
that is operated in Parallel with the Idaho Power System.

NON-EXPORT CONTROL SYSTEM

1. Non-Export Systems must incorporate one of the following three options:

a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, Energy
Management System, or other customer facility hardware or software system(s) may be used to
ensure power is never exported across the Interconnection Point. To ensure that Inadvertent
Export of power is limited to acceptable levels, all of the following conditions must be met: (a)
inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent
Export; (c) the DER must disconnect from the Company’s distribution system or halt energy
production within two seconds after the period of continuous Inadvertent Export exceeds 30
seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur
as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which
results in loss of control signal, loss of control power or single component failure or related control
sensing of the control circuitry.

b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a
reverse power relay protective function must be implemented at the Interconnection Point. The
default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total
Nameplate Capacity, with a maximum 2.0 second time delay.

Idaho Power Company Original Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM (Continued)

c. Option 3: (“Minimum Power Protection”): To ensure at least a minimum amount of
power is imported at all times (and, therefore, that power is not exported), an under-power
protective function may be implemented at the Interconnection Point. The default setting for this
non-export control system, when used, shall be 5% (import) of the DERs Total Nameplate
Capacity, with a maximum two (2) second time delay.

2. Control System Failure: Where applicable, any failure of the Customer’s DER control
system for 30 seconds or more, which includes, but is not limited to; the internal transfer relay, energy
management system, or other Customer facility hardware or software system(s) intended to prevent the
reverse power flow, shall cause the Customer’s DER to enter a safe operating mode whereby the
production of energy from the Non-Export DER is autonomously limited to an amount that shall not
cause Inadvertent Export to occur until such time that the Customer has reestablished real power
output control of the non-export control system.

UNAUTHORIZED INADVERTENT EXPORT

Inadvertent Export exceeding three hours of the DER Total Nameplate Capacity in any 30-day
period will be defined as unauthorized Inadvertent Export, and the following steps will be followed for
Customers with Non-Exporting Systems:

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedule 1, Residential and Schedule 7, Small General Non-Exporting
Systems, the Customer Generator must rectify Inadvertent Export within 30 days after receipt of
the notification by Idaho Power that the Non-Exporting System has exceeded the Inadvertent
Export limit. If the Customer Generator has not rectified Inadvertent Export after 30 days, at the
Customer’s election, one of the following actions will occur:

i. The Customer Generator System disconnect will be placed in the open
position until the issue that caused the export is remedied. A Company inspection will be
required before the Non-Exporting System can interconnect to the Company’s system; or,

ii. If the Customer does not elect to open the disconnect, the Customer
Generator will be placed on Schedule 6 or Schedule 8, as appropriate, and subject to
applicable provisions of Section 2. If the Customer elects to be placed on Schedule 6 or
Schedule 8, the Customer will be given the option to submit an additional application and
be moved back to Schedule 1 or Schedule 7, as appropriate, after 180 days.
Idaho Power Company Original Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER

UNAUTHORIZED INADVERTENT EXPORT (Continued)

b. For Schedules other than Schedule 1 or Schedule 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.

In addition to Section 1 and 3, the following section is applicable to all Customers requesting
interconnection of Non-Exporting Systems with Total Nameplate Capacity of 3 MVA or greater.

CUSTOMER GENERATOR INTERCONNECTION PROCESS

1. Customer Generator shall pay the actual costs of all required interconnection studies. Any
difference between the deposit (if required) and the actual cost of the study shall be paid by or refunded
to Customer Generator, as appropriate. If, during the course of preparing a study, the Company incurs
costs in excess of the deposit amount, the Company may require that the deposit amount be replenished
in an amount equal to the estimated costs for completion of the study. If a deposit amount sufficient to
pay for completion of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Customer Generator Interconnection Process.

3. Application. The Customer Generator will submit a completed interconnection application
in the form posted on the Company’s website. The application form includes a general description of the
DER and its location. The application includes payment of an application fee to be applied against costs
the Company incurs to perform the Feasibility Study described below. The amount of the application fee
is $1,000.

4. Study Agreements. Subsequent to the Customer Generator submitting an Application,
the Customer Generator will be offered a series of study agreements. The individual study agreements
establish the time to perform the study, and the deposit the Customer Generator is to provide prior to
commencement of the study. The studies consist of:

Idaho Power Company Original Sheet No. 68-16
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued)

a. The Feasibility Study: The Feasibility Study is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed DER in a manner that
conforms with good utility practices and the National Electric Safety Code. The Feasibility Study
Agreement states that no deposit is required because the application fee covers the deposit.

b. The System Impact Study: For higher complexity projects, the System Impact
Study provides a detailed assessment of the distribution and/or transmission system adequacy to
accommodate the DER through the evaluation of equipment capabilities and electrical
performance requirements. This step may not be necessary for some projects depending on the
size and location of the project. The System Impact Study Agreement includes a deposit of
$2,000 for a distribution system impact study or a $10,000 deposit for a transmission system
impact study.
c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Customer
Generator with an increasingly more refined and detailed report that, among other things, will present a
list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s
cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered
to meet Customer Generator’s construction schedule, the Company will request advance funding by the
Customer Generator to cover these equipment costs.

5. Customer Generator Interconnection Agreement. The Customer Generator
Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of
the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement
template included in this schedule.

INTERCONNECTION FACILITIES REQUIREMENTS

DER greater than 3 MVA Total Nameplate Capacity will require additional Company-Furnished
Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA
Attachment 1.

Idaho Power Company Original Sheet No. 68-17
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

COST OF INTERCONNECTION FACILITIES

The Customer Generator will pay all costs of interconnecting a Generation Facility to the
Company’s system. Costs of interconnection include the costs of furnishing and constructing required
Upgrades, which will be determined pursuant to Rule H. To the extent that additional facilities not
provided for under Rule H, including transmission and/or substation facilities, are required to interconnect
the requested Generation Facility, special arrangements will be made in a separate agreement between
the Customer Generator and the Company.

Each request for interconnection will go through the Customer Generator Interconnection
Process. Throughout the Customer Generator Interconnection Process, the Company will periodically
bill the Customer Generator for engineering costs incurred or obligated. Failure to pay an invoice within
the time specified in the invoice will result in the suspension of work on the interconnection. Customer
Generator can end the Customer Generator Interconnection Process at any time. If Customer Generator
decides to end the Customer Generator Interconnection Process prior to completion, the Company will
either refund any monies held for security that have not been spent or obligated, or issue an invoice to
Customer Generator for costs incurred prior to cancellation.

SYSTEM PROTECTION, DER METERING, AND DER COMMUNICATION MAINTENANCE CHARGE

The Customer shall pay the actual costs of System Protection, DER metering, and DER
communication equipment, as identified in the study process, prior to the start of Parallel operations. The
Customer will pay a Maintenance Charge of 0.59 percent per month times the investment in the System
Protection, DER metering, and DER communication equipment. The Customer Generator will also be
responsible for any applicable monthly charges as outlined in Attachment 1 of the CGIA.

Idaho Power Company Original Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT

This Uniform Customer Generator Interconnection Agreement (“Agreement”) is entered to be
effective as of the ____ day of __________, 20___ (“Effective Date”), between
____________________________, (“Customer Generator”) and Idaho Power Company (the
“Company”). Customer Generator and the Company may also be referred to individually as a “Party” or
collectively as the “Parties.” Unless explicitly noted otherwise, the term “days” refers to calendar days.

RECITALS

A. Customer Generator owns or operates a Customer Generator System that qualifies for
service under Idaho Power’s Commission-approved Schedule 68 which is subject to change from time
to time pursuant to Commission order.

B. The Customer Generator System to be interconnected and operate in Parallel with the
Company’s system pursuant to this Agreement is more particularly described in Attachment 1.

AGREEMENT

For and in consideration of the mutual covenants and provisions set forth in this Agreement, and
other good and valuable consideration, the receipt of which is hereby acknowledged, the Parties
intending to be legally bound agree as follows:

1. Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth
above, and such Recitals are incorporated herein by this reference.

2. Defined Terms. Capitalized terms not defined in this Agreement shall have the meaning
given to them in Schedule 68.

3. Schedule 68. Schedule 68 is incorporated into this Agreement by this reference and this
Agreement shall be interpreted in conjunction with Schedule 68; in the event of a conflict between
Schedule 68 and this Agreement, Schedule 68 shall prevail. This Agreement and Schedule 68 provide
terms and conditions under which the Customer Generator System will interconnect and operate in
Parallel with the Company’s transmission/distribution system.

4. Entire Agreement. This Agreement, in conjunction with Schedule 68, constitutes the full
and entire understanding and agreement between the Parties regarding the subjects set forth herein and
supersede all prior agreements and understandings related thereto. Nothing in this Agreement is
intended to affect any other agreement between the Company and Customer Generator regarding
subjects outside the terms of this Agreement and Schedule 68.
Idaho Power Company Original Sheet No. 68-19
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

5. Attachments. The following Attachments 1 – 6 are attached hereto and incorporated by
this reference:

Attachment 1 – Description and Costs of the Customer Generator System, Interconnection
Facilities, and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Customer Generator System,
Interconnection Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones for Interconnecting the Customer Generator System.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Customer Generator System.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Customer Generator
System and Best Estimate of Upgrade Costs.

6. Effective Date, Term, Termination and Disconnection.

6.1 Term of Agreement. Unless earlier terminated pursuant to the terms hereof, this
Agreement shall remain in effect from the Effective Date for as long as Customer Generator
System is eligible for service under Schedule 68.

6.2 Termination for Cause. If either Party materially breaches this Agreement and the
material breach is not cured within 10 days after the non-breaching Party gives the breaching
Party written notice thereof, the non-breaching Party may elect to terminate this Agreement by
giving the breaching Party notice of the termination; provided, however, that if the nature of the
breach is such that it could not reasonably be cured within the 10 day period, then the non-
breaching Party may terminate this Agreement immediately upon providing written notice to the
breaching Party. If the Company terminates this Agreement for breach by the Customer
Generator and it is later determined that Customer Generator did not breach the Agreement, or
the breach was excusable, the rights and obligations of the Parties will be the same as if the
termination has been issued for the convenience of the Company pursuant to Section 6.3 below.
Idaho Power Company Original Sheet No. 68-20
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

6.3 Termination for Convenience. The Company may terminate or suspend this
Agreement at any time without cause and without penalty, on 10 days’ written notice to the
Customer Generator. The Customer Generator may terminate or suspend this Agreement at any
time without cause and without penalty by discontinuing Parallel operation of Customer’s
Generator System, or discontinuing taking electric service from the Company, and providing the
Company with 10 days’ written notice of the same.

6.4. Effect of Termination. Upon termination or expiration of this Agreement pursuant
to this Section 6, Idaho Power will disconnect the Customer Generator System from the
Company’s transmission/distribution system. Upon termination or expiration of this Agreement,
all obligations of the Parties (other than those obligations that expressly or by nature survive
termination) shall terminate.

7. Land Rights. Customer Generator hereby grants to Idaho Power for the term of this
Agreement all necessary rights-of-way and easements to install, operate, maintain, replace, and remove
Idaho Power’s Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate and
continuing access rights on the property of Customer Generator. Customer Generator warrants that it
has procured sufficient easements and rights-of-way from third parties so as to provide Idaho Power with
the access described above. All documents granting such easements or rights-of-way shall be subject
to Idaho Power’s approval and in recordable form.

8. Assignment.

8.1 This Agreement may be assigned by either Party upon twenty-one (21) calendar
days prior written notice and opportunity to object by the other Party; provided that:

8.2 Either Party may assign this Agreement without the consent of the other Party to
any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.

8.3 The Customer Generator has the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing financing
for the Generation Facility, provided that the Customer Generator will promptly notify the
Company of any such contingent assignment.
Idaho Power Company Original Sheet No. 68-21
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

8.4 Any attempted assignment that violates this Section 6 is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall the non-assigning Party’s
obligations be enlarged, in whole or in part, by reason thereof. An assignee is responsible for
meeting the same financial, credit, and insurance obligations as the Customer Generator. Where
required, consent to assignment will not be unreasonably withheld, conditioned or delayed.

9. Indemnity. To the fullest extent permitted by law, Customer Generator shall indemnify,
defend, reimburse, and hold harmless the Company and its successors and their respective directors,
officers, members, employees, representatives, and agents (collectively, the “Indemnitees”), from, for,
and against any and all third-party allegations, claims, liens, liabilities, losses, demands, damages,
expenses, suits, actions, proceedings, judgments, and costs of any kind whatsoever, including, without
limitation, settlement costs, court costs, and attorneys’ and expert witness fees and expenses
(collectively, “Damages”), whether actual or merely alleged, and whether directly incurred or incurred by
a third party, arising out of, or relating to a) the negligent acts, omissions, or willful misconduct of
Customer Generator, b) a violation of federal or state law, regulation, statute, or ordinance, or c)
Customer Generator’s material breach of this Agreement. If the Company seeks indemnification from
the Customer Generator, the Company shall: (i) notify Customer Generator of the assertion of any claim;
(ii) provide reasonable assistance (at Customer Generator’s expense) in connection with the defense;
and (iii) be entitled to pre-approve any settlement.

9.1 The Parties shall at all times indemnify, defend, and hold the other Party harmless
from, any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of or resulting from
the other Party’s action or failure to meet its obligations under this Agreement on behalf of the
indemnifying Party, except in cases of gross negligence or intentional wrongdoing by the
indemnified Party.

9.2 If an indemnified person is entitled to indemnification under this article as a result
of a claim by a third party, and the indemnifying Party fails, after notice and reasonable opportunity
to proceed under this article, to assume the defense of such claim, such indemnified person may
at the expense of the indemnifying Party contest, settle or consent to the entry of any judgment
with respect to, or pay in full, such claim. Failure to defend is a Material Breach.
Idaho Power Company Original Sheet No. 68-22
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

9.3 If an indemnifying party is obligated to indemnify and hold any indemnified person
harmless under this article, the amount owing to the indemnified person shall be the amount of
such indemnified person’s actual loss, net of any insurance or other recovery.

10. Force Majeure Event. Neither Party shall be liable for any breach, default, or delay in
the performance of the obligations under this Agreement if and to the extent such default or delay is
caused by fire, flood, earthquake, elements of nature or acts of God, riots, civil disorder, rebellions or
revolutions, strikes, lockouts or other industrial disturbances, unanticipated changes in governmental
laws and regulations, or any other cause beyond the reasonable control of such Party (a “Force Majeure
Event”); provided the non-performing Party is without fault in causing such breach, default, or delay, and
such breach, default or delay could not have been prevented by reasonable precautions and cannot
reasonably be circumvented by the non-performing Party through the use of alternate sources, work-
around plans, or other means. The Party claiming a Force Majeure Event must give the other Party
immediate written notice, no later than five (5) calendar days of the Party’s discovery of the Force Majeure
Event, and the time for resumption of performance (if applicable) by that Party. The suspension of
performance shall be of no greater scope and of no longer duration than is required by the Force Majeure
Event.

11. Insurance. During the term of this Agreement, Customer Generator shall secure and
continuously carry the following insurance coverage Comprehensive General Liability Insurance for both
bodily injury and property damage with limits equal to $1,000,000, each occurrence, combined single
limit. The deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property. Such insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

Idaho Power Company Original Sheet No. 68-23
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

11.1 An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and

11.2 A provision stating that such policy shall not be canceled, or the limits of liability
reduced without sixty (60) days’ prior written notice to Idaho Power.

11.1 Customer Generator to Provide Certificate of Insurance. As required in
Paragraph 11 herein and annually thereafter, Customer Generator shall furnish the Company a
certificate of insurance, together with the endorsements required therein, evidencing the coverage
as set forth above.

11.2 Customer Generator to Notify Idaho Power of Loss of Coverage. If the insurance
coverage required by Paragraph 11.1 shall lapse for any reason, Customer Generator will
immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific
reason for the lapse and the steps Customer Generator is taking to reinstate the coverage.
Failure to provide this notice and to expeditiously reinstate or replace the coverage will constitute
grounds for a temporary disconnection under Section 9.2 and will be a Material Breach.

12. Miscellaneous.

12.1 Governing Law. This Agreement shall be interpreted, applied and enforced in
accordance with the laws of the State of Idaho without regard to its conflicts of law principles.

12.2 Net Salvage Value. If removal of the Interconnection Facilities is required, within
sixty (60) days after the termination or expiration of this Agreement, Idaho Power will provide
Customer Generator an estimate of the remaining value of the Company-Furnished
Interconnection Facilities required under Schedule 68 and/or described in this Agreement, less
the cost of removal and transfer to Idaho Power’s warehouse (“Net Salvage Value”). If Customer
Generator elects not to purchase the Interconnection Facilities from the Company, Idaho Power
will reimburse the Customer Generator the Net Salvage Value as estimated by Idaho Power.
Customer Generator shall invoice Idaho Power for the same and Customer Generator shall have
the right to offset the invoice amount with amounts due to Idaho Power from Customer Generator.

Idaho Power Company Original Sheet No. 68-24
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13. Notices. Any changes to the below contacts must be made via written notice pursuant to
Section 13.1.

13.1 Written Notice. Where required herein, written notice shall be deemed to have
been duly served when (i) delivered in person, or (ii) sent by mail or courier, return receipt
requested, at the address for each Party as follows:

If to the Customer Generator:
Customer Generator:
Attention:
Address:
City: State: Zip:

If to the Company:
Company:
Attention:
Address:
City: State: Zip:

Idaho Power Company Original Sheet No. 68-25
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13.2 Designated Operating Representative. The Parties may also designate an
operating representative to communicate regarding administration of this Agreement, as well as
operations and maintenance of such Party’s facilities; provided that, any “written notice” required
by this Agreement must be made as set forth in the above Section 13.1.

Customer Generator’s Operating Representative:
Customer Generator:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

IN WITNESS WHEREOF, the Parties hereto enter this Uniform Customer Generator Agreement
to be effective as of the Effective Date.

Idaho Power Company
Print:
Sign:
Title:
Date:

Customer Generator
Print:
Sign:
Title:
Date:
Idaho Power Company Original Sheet No. 68-26
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 1

Description and Costs of the Customer Generator System, Interconnection Facilities and Metering
Equipment

In this attachment, the Customer Generator System and Interconnection Facilities, including
Special Facilities and upgrades, are itemized and identified as being owned by the Customer Generator
or the Company. As provided in Schedule 68, Cost of Interconnection Facilities, the Company will provide
a best estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Customer Generator System, Interconnection Facilities, Metering
Equipment and Upgrades

Idaho Power Company Original Sheet No. 68-27
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Customer Generator________________________ Date______________

Idaho Power Company Original Sheet No. 68-28
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Customer Generator’s Needs

The Company shall also provide requirements that must be met by the Customer Generator prior
to initiating Parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Customer Generator, based upon information provided by the Customer Generator. The Company will
specify the equipment required on the Company’s system to meet the Facility’s reactive power
requirements. These specifications will include but not be limited to equipment specifications, equipment
location, Company-provided equipment, Customer Generator provided equipment, and all costs
associated with the equipment, design and installation of the Company-provided equipment. The
equipment specifications and requirements will become an integral part of this Agreement. The
Company-owned equipment will be maintained by the Company, with total cost of purchase, installation,
operation, and maintenance, including administrative cost to be reimbursed to the Company by the
Customer Generator. Payment of these costs will be in accordance with Schedule 68 and the total
reactive power cost will be included in the calculation of the monthly facilities charge.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 68, this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

Idaho Power Company Original Sheet No. 72-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection
Agreement. The interconnection procedures and requirements for customer-owned generation facilities,
including those that qualify for Schedule 6, Schedule 8, Schedule 84 or non-export customer generation
are governed by Schedule 68.

APPLICABILITY

Service under this schedule applies to the construction, operation, maintenance, Upgrade,
Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely
interconnect a Seller's Generation Facility to the Company's system.

DEFINITIONS

Additional Applicant is a person or entity whose request for electrical connection requires the
Company to utilize existing Interconnection Facilities which are subject to a Vested Interest.

Company is the Idaho Power Company.

Connected Load is the combined peak kW of installed energy generation plus the total nameplate
kW rating of the Seller or customer's motors and other energy consuming devices.

Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or
construction of Company furnished Interconnection Facilities.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Seller to the Company's system,
including enclosures or other equipment as may be required to ensure that only the Company will have
access to certain of the devices.

First Energy Date is the date when the Seller begins delivering energy to the Company's system.

Generation Facility means equipment used to produce electric energy at a specific physical
location which meets the requirements to be a Qualifying Facility.

Generator Interconnection Process is the Company’s Generation Facility interconnection
application, engineering review and construction process. The intent of the Generator Interconnection
Process is to ensure a safe and reliable generation interconnection in compliance with all applicable
regulatory requirements, good utility practices and national safety standards.

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow the delivery of energy from the Seller's
Generation Facility to the Company's system, including, but not limited to, Special Facilities,
Disconnection Equipment and Metering Equipment.
Idaho Power Company Original Sheet No. 72-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

DEFINITIONS (Continued)

Interconnection Point is the point where the Seller’s conductors connect to the facilities owned by
the Company.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Seller's Generation Facility and the Company's system. These facilities are not
eligible for Vested Interest.

OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open Access
Transmission Tariff.

Protection Equipment is the circuit-interrupting device, protective relaying, and associated
instrument transformers.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of
the Code of Federal Regulations.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles or equipment.

Seller is a non-utility generator who has contracted or will contract with the Company to
interconnect a Generation Facility to the Company’s system to sell electric energy to the Company.

Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the
Seller.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the Seller's
Generation Facility to the Company's system.

Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of
Seller-Furnished Facilities.

Upgrades are those improvements to the Company's existing system which are reasonably
required by good practices and the National Electric Safety Code to safely interconnect the Seller’s
Generation Facility. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Vested Interest is the claim for refund that a Seller, person or entity holds in a specific portion of
Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the date the
Company completes construction of its portion of the Interconnection Facilities unless fully refunded
earlier.
Idaho Power Company Original Sheet No. 72-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Sellers requesting interconnection to the Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to
be in full compliance with all good utility practices, National Electric Safety Code, and all other applicable
federal, state, and local safety and electrical codes and standards at all times.

The Seller shall:

1. Submit proof to the Company that all licenses, permits, inspections, and approvals
necessary for the construction and operation of the Seller's Generation and Interconnection Facilities
under this schedule have been obtained from applicable federal, state, or local authorities.

2. Submit the designs, plans, specifications, and performance data for the Generation
Facility and Seller-Furnished Facilities to the Company for review. The Company’s acceptance shall not
be construed as confirming or endorsing the design, or as a warranty of safety, durability, or reliability of
the Generation Facility or Seller-Furnished Facilities. The Company will retain the right to inspect this
equipment at its discretion.

3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and Seller-
Furnished Facilities have been completed, and that all features and equipment of the Seller’s Generation
Facility and Seller-Furnished Facilities are capable of operating safely to commence deliveries of Energy
into the Company's system.

4. Provide and maintain adequate protective equipment sufficient to prevent damage to the
Generation Facility, Seller-Furnished Facilities and any other Seller-owned facilities in conformance with
all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical
and safety codes and requirements as described within this Schedule.

6. Provide a 24-hour telephone contact(s). This contact will be used by the Company to
arrange for repairs and inspections or in case of an emergency. The Company will make its best effort
to arrange repairs and inspections during normal business hours and to notify the Seller of such
arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller
can obtain information about Company activity impacting the Seller’s facility.

Idaho Power Company Original Sheet No. 72-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection
Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation
and Interconnection Facilities from the Company’s system.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed at a location within 10 feet of the Interconnection Point or exact,
permanent instructions posted at the Interconnection Point indicating the precise location of the
Disconnection Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the Seller's
operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or may
otherwise adversely affect the Company's equipment, personnel, or service to its customers, the
Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by
operation of the disconnection device or by any other means the Company deems necessary to
adequately disconnect the Seller’s Generation and Interconnection Facilities from the Company’s system.
At such time as the unsafe condition is remedied or other condition adversely affecting the Company is
resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Seller’s Generation and Interconnection Facilities in the event
of any planned or unplanned maintenance or repair of the Company’s system connected to the Seller’s
Generation and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior
notice will be provided. In the event of planned repairs, the Company will attempt to notify the Seller of
the time and duration of the planned outage.

The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in the
event that any terms and conditions of any applicable Company tariff or contract enabling the
interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or
delinquent.

All expenses of disconnection and reconnection incurred by the Company will be billed to the
Seller.

Idaho Power Company Original Sheet No. 72-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

The Company will establish the settings of Protection Equipment to disconnect the Seller’s
Generation Facility and Interconnection Facilities for the protection of the Company’s system and
personnel consistent with good utility practices. If the Seller attempts to modify, adjust or otherwise
interfere with the protection equipment or its settings as established by the Company, such action may
be grounds for the Company's refusal to continue interconnection of the Seller’s Generation and
Interconnection Facilities to the Company’s system.

GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Seller’s Generation Facility and/or Interconnection Facilities designating
the existence of the Seller’s Generation Facility as required by good utility practices.

3. The Seller will be required to submit all specific designs, equipment specifications, and
test results of the Seller-Furnished Facilities to the Company for review. Upon receipt of the design and
equipment specifications, the Company will review the design and equipment specifications for
conformance with applicable electrical and safety codes and standards.

OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as well as
any Seller-Furnished Facilities transferred to the Company.

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES

The following section is applicable to all Sellers requesting interconnection of non-utility
generation.

SPECIFIC PROJECT REQUIREMENTS

1. Generation Facilities Less than 1 MW Nameplate Rating

The following requirements are for Generation Facilities with nameplate ratings of less than 1
MW.
Idaho Power Company Original Sheet No. 72-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

SPECIFIC PROJECT REQUIREMENTS (Continued)

a. The Company shall procure, install, own and maintain Metering Equipment to
record energy deliveries to the Company. This metering will be separate from any other metering
of the Seller’s load and may be located on either side of the Interconnection Point. All acquisition,
installation, maintenance, inspection and testing costs related to Meter Equipment installed to
measure the Seller’s energy deliveries to the Company shall be borne by the Seller.

b. The Seller is responsible for all costs incurred by the Company for the review,
evaluation and testing of Seller supplied designs and equipment regardless as to the outcome of
the review or test results.

c. The Seller, upon completion of installation and prior to interconnection of the
Generation Facility to the Company’s system, will provide the Company with certification from a
professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility
and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable
electrical and safety codes to enable safe and reliable operation.

d. The Seller will obtain and provide to the Company an annual certification and
testing by a professional engineer licensed in the State of Idaho, certifying the ongoing
compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the
Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In
the event the Company does not receive and accept the annual certification within thirty (30) days
of the annual anniversary date of the agreement, the project will be disconnected from the
Company’s system until such time as the certification is completed and accepted by the Company.

e. In addition to the requirements specified in sections a through d, Generation
Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the
following:

i. If the Company owns the transformer interconnecting the Seller’s
Generation Facility, then the Seller may own and maintain a secondary voltage
disconnection device that can be operated by both the Seller and the Company.

ii. If the Seller owns the transformer interconnecting the Seller’s Generation
Facility, then the Company will own, operate and maintain a primary voltage disconnection
device at the Seller’s expense.

iii. The Company will construct, own, operate and maintain all protective
relays and any associated equipment required to operate the protective relays.

2. Generation Facilities Greater Than 1 MW Nameplate Rating

The Company will own, maintain and operate all Interconnection Facilities and Disconnection
Equipment at the Seller’s expense.
Idaho Power Company Original Sheet No. 72-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS

1. Seller shall pay the actual costs of all required interconnection studies. Any difference
between the deposit (if required) and the actual cost of the study shall be paid by or refunded to Seller,
as appropriate. If, during the course of preparing a study, the Company incurs costs in excess of the
deposit amount, the Company may require that the deposit amount be replenished in an amount equal
to the estimated costs for completion of the study. If a deposit amount sufficient to pay for completion of
the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Generator Interconnection Process.

3. The deposit amounts for Generation Facilities up to 30 MW are specified in this schedule.
Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-approved Large
Generator Interconnection Procedures posted on the Company’s website.

4. Application. The Seller will submit a completed interconnection application in the form
posted on the Company’s website. The application form includes a general description of the Generation
Facility and its location. The application includes payment of an application fee to be applied against
costs the Company incurs to perform the Feasibility Study described below. The amount of the
application fee is $1,000 for a Generation Facility up to 30 MW.

5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the
Seller will be offered a series of study agreements. The individual study agreements establish the time
to perform the study and the deposit the Seller is to provide prior to commencement of the study. The
deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for
unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of:

a. The Feasibility Study: The Feasibility Study includes a general review of project
impact, e.g. exceeding equipment capabilities and violation of electrical performance
requirements. The Feasibility Study Agreement states that no deposit is required, since the
deposit is covered by the application fee.

b. The System Impact Study: The System Impact Study provides a detailed
assessment of the distribution and/or transmission system adequacy to accommodate the
Generation Facility through the evaluation of equipment capabilities and electrical performance
requirements. This step may not be necessary for some projects depending on the size and
location of the project. The System Impact Study Agreement includes a deposit of $2,000 for a
distribution system impact study or a $10,000 deposit for a transmission system impact study.

Idaho Power Company Original Sheet No. 72-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Seller with
an increasingly more refined and detailed report that, among other things, will present a list of required
Interconnection Facilities and a non-binding, good faith estimate of Seller’s cost responsibility for the
Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s
construction schedule, the Company will request advance funding by the Seller to cover these equipment
costs.

6. Generator Interconnection Agreement. The Generator Interconnection Agreement
(“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the Uniform
Interconnection Agreement template included in this schedule.

COST OF INTERCONNECTION FACILITIES

All Interconnection Facilities provided under this schedule will be valued at the Company's
Construction Cost and/or the Transfer Cost for vesting purposes, as well as for operation and
maintenance payment obligations.

PAYMENT FOR INTERCONNECTION FACILITIES

Unless specifically agreed otherwise by written agreement between the Seller and the Company,
the Seller will pay all costs of interconnecting a Generation Facility to the Company's system. Costs of
interconnection include the costs of furnishing and constructing required Interconnection Facilities,
including Upgrades.

Each request for interconnection will go through the Generator Interconnection Process.
Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for costs
incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result in
suspension of work on the interconnection and if the suspension of work extends beyond thirty (30)
calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end
the Generator Interconnection Process at any time. If Seller decides to end the Generator
Interconnection Process prior to completion, the Company will either refund any monies held for security
that have not been spent or obligated, or issue an invoice to Seller for costs incurred prior to cancellation.
Idaho Power Company Original Sheet No. 72-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

SECURITY FOR PAYMENT OF INTERCONNECTION COSTS

Sellers will provide adequate security for payment of the costs of the Generator Interconnection
Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance
with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s
OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following
ways

1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are not
required to provide additional security. The Company’s minimum credit standards for unsecured credit
are described in Attachment L to the OATT.

2. Sellers that do not meet the credit worthiness standards for unsecured credit will be
notified of the reason for the determination and shall be given the option to provide alternative security
acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow account,
provide a letter of credit or provide guarantee of payment by another person or entity which meets the
credit worthiness standards for unsecured credit. Arrangements for alternative security must be
acceptable to Idaho Power.

TRANSFER OF INTERCONNECTION FACILITIES

Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate
ratings greater than 100 kW.

1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires
to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply:

a. Prior to the beginning of construction, the Seller shall cause the contractor that is
constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the
Company as an additional insured in the amount of not less than $1,000,000 under the
contractor's general liability policy.

b. The Company will provide the Seller's contractor with construction and material
specifications and will have final approval of the design of the Seller-Furnished Facilities.

c. During construction and upon completion, the Company will inspect the Seller-
Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne
by the Seller.
Idaho Power Company Original Sheet No. 72-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

TRANSFER OF INTERCONNECTION FACILITIES (Continued)

d. If the Seller-Furnished Facilities meet the Company's design, material and
construction specifications, are free from defects in materials and workmanship, and the Seller
has provided the Company with acceptable easements, bills of sale and assurance against labor
or materials liens, the Company will accept ownership effective as of the First Energy Date. In
the bill of sale, the Seller will warrant to the Company that the Seller-Furnished Facilities are free
of any liens or encumbrances and will be free from any defects in materials and workmanship for
a period of one year from the First Energy Date.

2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and the
Company desires to accept any Seller-Furnished Facilities, the following will apply:

a. The Company will inspect the facilities proposed for sale to determine if they meet
the Company's design, material and construction specifications.

b. The Company will determine the Transfer Cost of such facilities. The Transfer
Cost will be equal to the depreciated Construction Cost the Company would have incurred if it
had originally constructed the facilities plus the cost, if any, of bringing the facilities into
compliance with the Company's design, material and construction specifications. Depreciation of
the facilities proposed for transfer will be determined on the same basis as the Company
depreciates its own facilities in accordance with the appropriate FERC account numbers for the
type and size of line or equipment involved. The time period used for the calculation of the
depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer
date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the same
time, the Company will pay the Seller in cash an amount equal to the depreciated Construction
Cost.

c. As a condition of the Company's acceptance, the Seller will provide the Company
with acceptable easements, bills of sale and acceptable assurance against labor and material
liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and
encumbrances and will be free from any defects in materials and workmanship for a period of one
year from the date of transfer.

d. Effective as of the date of the transfer, the Company will operate and maintain the
transferred facilities.

VESTED INTEREST

A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company
completes construction of its portion of the Interconnection Facilities.
Idaho Power Company Original Sheet No. 72-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

VESTED INTEREST (Continued)

1. The Company will provide a refund payment to the Seller, person or entity holding a
Vested Interest in Company-owned Interconnection Facilities when an Additional Applicant shares use
of those Interconnection Facilities.

2. The refund payment will be based on one of the following options:

Option One – An Additional Applicant may choose to pay an amount determined by this
equation:

Vested Interest Amount = A x B x C where:

A = Load Ratio: The Connected Load of the Additional Applicant divided by the
sum of the Connected Load of the Additional Applicant and the Connected
Load of the Seller, person or entity holding a Vested Interest.

B = Distance Ratio: The length of jointly used Special Facilities divided by the
length of the vested Special Facilities.

C = Original Interconnection Cost: the sum of the Company's Construction Cost
and any Transfer Costs for the Interconnection Facilities to which the Additional
Applicant intends to connect and share usage.

Option Two – An Additional Applicant may choose to pay the current Vested Interest, in
which case the Vested Interest will transfer to the Additional Applicant and, as such, the
Additional Applicant will hold the Vested Interest and be eligible to receive Vested Interest
refunds.

If Option One is selected, the Additional Applicant has no Vested Interest and the previous Vested
Interest holder remains the Vested Interest holder. The Vested Interest holder’s Vested Interest
will be reduced by the newest Additional Applicant’s payment.

3. The Additional Applicant will pay the Company the amount of the Vested Interest
refund(s).

4. The Seller, person or entity holding a Vested Interest will be eligible to receive refunds up
to 80 percent of their original interconnection cost. Additional Applicants that become Vested Interest
holders will be eligible to receive refunds up to their total contribution less 20 percent of the original
interconnection cost. Vested Interest refunds will be funded by no more than 4 Additional Applicants
during the 5-year period following the date the Company completes construction of its portion of the
Interconnection Facilities.

.
Idaho Power Company Original Sheet No. 72-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

VESTED INTEREST (Continued)

5. In no circumstance will Vested Interest refunds exceed 100 percent of the refundable
portion of any party's cash payment to the Company.

6. Vested Interest refund payments may be waived by notifying the Company in writing.

7. All existing agreements’ refund provisions will be governed and administered under the
provisions in effect at the time the agreement was entered into between the Company and Seller or
Additional Applicant.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as well as
any Seller-Furnished Facilities transferred to the Company. Seller will pay the Company a monthly
operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost
paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in
accordance with the following tables:

TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV
Yea 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40% 0.41%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67% 0.70%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14% 0.40%

TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70%

The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a
percentage of the applicable original interconnection investment. These monthly operating and
maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for Table
1 and 0.70% for Table 2.
Idaho Power Company Original Sheet No. 72-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the operation
and maintenance charge related to those existing Interconnection Facilities for the Seller’s
interconnection will be computed at the applicable levelized rate designated at 36+ years.

The cost upon which an individual Seller's operation and maintenance charge is based will be
reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the
monthly operation and maintenance charge on the amount they paid as an Additional Applicant.

Seller-Furnished Facilities not transferred to the Company will be operated and maintained by the
Seller at the Seller's sole risk and expense.

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)

This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________,
20___, between ____________________________, hereinafter called “Seller,” and Idaho Power
Company, hereinafter called “Company.”

RECITALS

A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power’s Commission-approved Schedule 72 and any successor schedule.

B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.

AGREEMENTS

1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72
or in the body of this Agreement.

2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions under
which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the Company’s
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72, Schedule
72 shall prevail.

Idaho Power Company Original Sheet No. 72-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s
power and other services that Seller may require will be covered under separate agreements. Nothing
in this Agreement is intended to affect any other agreement between the Company and Seller.

4. Attached to this Agreement and included by reference are the following:

Attachment 1 – Description and Costs of the Generation Facility, Interconnection Facilities,
and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones For Interconnecting the Generation Facility.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Seller’s Generation Facility.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.

5. Effective Date, Term, Termination and Disconnection.

5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller’s Generation Facility is eligible for service under Schedule 72.

5.2 Termination.

5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.

5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
Idaho Power Company Original Sheet No. 72-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)
AGREEMENTS (Continued)

5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation
Facility will be disconnected from the Company’s transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities and
obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.

5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of
the practices, methods and acts engaged in or approved by a significant portion of the electric
industry during the relevant time period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made,
could have been expected to accomplish the desired result at a reasonable cost consistent with
good business practices, reliability, safety and expedition. Good Utility Practice is not intended
to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to be
acceptable practices, methods, or acts generally accepted in the region. Good Utility Practice
includes compliance with WECC or NERC requirements. Payment of lost revenue resulting from
temporary disconnection shall be governed by the power purchase agreement.

5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company’s transmission/distribution system, the Company’s
Interconnection Facilities or the equipment of the Company’s customers; or (3) that, in the
case of the Seller, is imminently likely (as determined in a non-discriminatory manner) to
cause a material adverse effect on the reliability and security of, or damage to, the
Generation Facility or the Seller’s Interconnection Facilities. Under Emergency
Conditions, either the Company or the Seller may immediately suspend interconnection
service and temporarily disconnect the Generation Facility. The Company shall notify the
Seller promptly when it becomes aware of an Emergency Condition that may reasonably
be expected to affect the Seller’s operation of the Generation Facility. The Seller shall
notify the Company promptly when it becomes aware of an Emergency Condition that may
reasonably be expected to affect the Company’s equipment or service to the Company’s
customers. To the extent information is known, the notification shall describe the
Emergency Condition, the extent of the damage or deficiency, the expected effect on the
operation of both Parties' facilities and operations, its anticipated duration, and the
necessary corrective action.
Idaho Power Company Original Sheet No. 72-16
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller’s Generation Facility and
temporarily disconnect the Generation Facility from the Company’s
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company’s transmission/distribution system. The Company will make
a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system, and/or
unplanned events, the Company may not be able to provide notice to the Seller prior to
interruption, curtailment or reduction of electrical energy deliveries to the Company. The
Company shall use reasonable efforts to coordinate such reduction or temporary
disconnection with the Seller.

5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller’s timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller’s
preferred schedule. Neither Party shall unreasonably withhold acceptance of the proposed
maintenance schedule.

5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage to
the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller’s protective relays will provide back-up protection for Idaho Power’s
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.

Idaho Power Company Original Sheet No. 72-17
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 72-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company’s
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of the
disconnection.

5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller’s Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company’s transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect within
a reasonable time, the Company may disconnect the Generation Facility. The Company
shall provide the Seller with reasonable notice of such disconnection, unless the
provisions of Article 5.3.1 apply.

5.3.7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility that
may have a material impact on the safety or reliability of the Company’s
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company’s prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.

5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company’s
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.

Idaho Power Company Original Sheet No. 72-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 72-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified nominal
operating voltage level.

5.4 Land Rights.

5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the term
of this Agreement all necessary rights-of-way and easements to install, operate, maintain,
replace, and remove Idaho Power's Metering Equipment, Interconnection Equipment,
Disconnection Equipment, Protection Equipment and other Special Facilities necessary or
useful to this Agreement, including adequate and continuing access rights on property of
Seller. Seller warrants that it has procured sufficient easements and rights-of-way from
third parties so as to provide Idaho Power with the access described above. All documents
granting such easements or rights-of-way shall be subject to Idaho Power's approval and
in recordable form.

5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct and
maintain Seller-furnished Interconnection Facilities upon, along and over any and all public
roads, streets and highways, then the use by Seller of such public right-of-way shall be
subordinate to any future use by Idaho Power of such public right-of-way for construction
and/or maintenance of electric distribution and transmission facilities and Idaho Power
may claim use of such public right-of-way for such purposes at any time. Except as
required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for
exercising its rights under this Paragraph 5.4.2.

Idaho Power Company Original Sheet No. 72-19
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under this
Paragraph 5.4.3.

5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior to
Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties agree
that the exercise by Idaho Power of any of the rights enumerated in Paragraphs 5.4.2 and
5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility Practices, (2)
equitably share the costs of installing, owning and operating jointly used facilities and
rights-of-way. If the Parties are unable to agree on the method of apportioning these
costs, the dispute will be submitted to the Commission for resolution and the decision of
the Commission will be binding on the Parties, and (3) shall provide Seller with an
interconnection to Idaho Power's system of equal capacity and durability as existed prior
to Idaho Power exercising its rights under this Paragraph 5.4.

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default.

6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided that:

6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
Idaho Power Company Original Sheet No. 72-20
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.

6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.

6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any indirect,
special, consequential, or punitive damages, except as authorized by this Agreement.

6.3 Indemnity.

6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.

6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions relating
to injury to or death of any person or damage to property, demand, suits, recoveries, costs
and expenses, court costs, attorney fees, and all other obligations by or to third parties,
arising out of or resulting from the other Party's action or failure to meet its obligations
under this Agreement on behalf of the indemnifying Party, except in cases of gross
negligence or intentional wrongdoing by the indemnified Party.

Idaho Power Company Original Sheet No. 72-21
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.3.3 If an indemnified person is entitled to indemnification under this article as a
result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such claim,
such indemnified person may at the expense of the indemnifying Party contest, settle or
consent to the entry of any judgment with respect to, or pay in full, such claim. Failure to
defend is a Material Breach.

6.3.4 If an indemnifying party is obligated to indemnify and hold any indemnified
person harmless under this article, the amount owing to the indemnified person shall be
the amount of such indemnified person's actual loss, net of any insurance or other
recovery.

6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation as
to which the indemnity provided for in this article may apply, the indemnified person shall
notify the indemnifying party of such fact. Any failure of or delay in such notification shall
be a Material Breach and shall not affect a Party's indemnification obligation unless such
failure or delay is materially prejudicial to the indemnifying party.

6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of Force Majeure”
means any cause beyond the control of the Seller or of the Company which, despite the exercise
of due diligence, such Party is unable to prevent or overcome. Force Majeure includes, but is not
limited to, acts of God, fire, flood, storms, wars, hostilities, civil strife, strikes and other labor
disturbances, earthquakes, fires, lightning, epidemics, sabotage, or changes in law or regulation
occurring after the Operation Date, which, by the exercise of reasonable foresight such party
could not reasonably have been expected to avoid and by the exercise of due diligence, it shall
be unable to overcome. If either Party is rendered wholly or in part unable to perform its
obligations under this Agreement because of an event of Force Majeure, both Parties shall be
excused from whatever performance is affected by the event of Force Majeure, provided that:

(1) The non-performing Party shall, as soon as is reasonably possible after the
occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
Idaho Power Company Original Sheet No. 72-22
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.

(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.

6.5 Default and Material Breaches.

6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a “Default” or an “Event of Default”), the non-defaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty (60)
days after service of such notice, or if the defaulting Party reasonably demonstrates to the
other Party that the Default can be cured within a commercially reasonable time but not
within such sixty (60) day period and then fails to diligently pursue such cure, then, the
non-defaulting Party may, at its option, terminate this Agreement and/or pursue its legal
or equitable remedies.

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.5.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material Breaches
must be cured as expeditiously as possible following occurrence of the breach.

Idaho Power Company Original Sheet No. 72-23
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry
the following insurance coverage:

7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.

7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and

(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days’ prior written notice to Idaho Power.

7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.

7.4 Seller to Notify Idaho Power of Loss of Coverage. If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.

Idaho Power Company Original Sheet No. 72-24
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

8. Miscellaneous.

8.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the State of Idaho without regard to
its conflicts of law principles.

8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value of
those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power’s nearest
warehouse (Net Salvage Value). If the Seller elects to obtain ownership of the Idaho Power
furnished Interconnection Facilities, the Seller will decline the Net Salvage Value and execute an
Asset Transfer Agreement. If the Seller elects not to obtain ownership of the Idaho Power
furnished Interconnection Facilities, the Seller may invoice Idaho Power for the Net Salvage Value
as estimated by Idaho Power, and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due to Idaho Power.

9. Notices.

9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered via email, delivered by recognized national
courier service, or sent by first class mail, postage prepaid, to the person specified below:

Idaho Power Company Original Sheet No. 72-25
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Seller:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company
Attention:
Address:
City: State: Zip:
Phone: Email:

9.2 Billing and Payment. Billings and payments shall be sent to the addresses set out
below:

Seller:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

9.3 Designated Operating Representative. The Parties may also designate operating representatives
to conduct the communications which may be necessary or convenient for the administration of
this Agreement. This person will also serve as the point of contact with respect to operations and
maintenance of the Party’s facilities.

Idaho Power Company Original Sheet No. 72-26
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Seller’s Operating Representative:

Seller:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

9.4 Changes to the Notice Information. Either Party may change this information by
giving five Business Days written notice prior to the effective date of the change.

10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.

For the Company
Name:
Title:
Date:

For the Seller
Name:
Title:
Date:

Idaho Power Company Original Sheet No. 72-27
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Attachment 1

Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment

In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and Metering
Equipment.

Attachment 2

One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________
Idaho Power Company Original Sheet No. 72-28
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 72-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)
AGREEMENTS (Continued)

Agreed to by:

For the Company __________________________ Date______________

For the Seller________________________ Date______________

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Seller’s Needs

The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Seller, based upon information provided by the Seller. The Company will specify the equipment required
on the Company’s system to meet the Facility’s reactive power requirements. These specifications will
include, but not be limited to, equipment specifications, equipment location, Company-provided
equipment, Seller provided equipment, and all costs associated with the equipment, design and
installation of the Company-provided equipment. The equipment specifications and requirements will
become an integral part of this Agreement. The Company-owned equipment will be maintained by the
Company, with total cost of purchase, installation, operation, and maintenance, including administrative
cost to be reimbursed to the Company by the Seller. Payment of these costs will be in accordance with
Schedule 72 and the total reactive power cost will be included in the calculation of the Monthly Operation
and Maintenance Charges specified in Schedule 72.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.
Idaho Power Company Original Sheet No. 73-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-1

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO

AVAILABILITY

In all electric area served by the Company in the State of Idaho.

APPLICABILITY

To Qualifying Facilities that intend to sell their output to the Company by either (i)
interconnecting to the Company’s electrical system at an interconnection point within the State of Idaho,
or (ii) delivering the output to the Company at a point of delivery (“POD”) on the Company’s electrical
system within the State of Idaho.

A Customer selling the output of any Qualifying Facility (including both Qualifying Facilities with
a maximum generating capability equal to or less than the Eligibility Cap and Qualifying Facilities with a
maximum generating capability greater than the Eligibility Cap) will be required to enter into a written
Energy Sales Agreement (“ESA”) with the Company in accordance with the contracting procedures set
forth in this tariff. Any such ESA is subject to the approval of the Idaho Public Utilities Commission
(“Commission”).

DEFINITIONS

Customer as used herein means any individual, partnership, corporation, association,
governmental agency, political subdivision, municipality, or other entity that owns an existing or
proposed Qualifying Facility.

Cogeneration Facility means equipment used to produce electric energy and forms of useful
thermal energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes,
through the sequential use of energy.

Daily Shape Adjustment means an adjustment to rates based on a difference between Heavy
Load rates and Light Load rates of $7.28 per MWh as established in Commission Order No. 30415.

Eligibility Cap means for all Qualifying Facilities except wind and solar Qualifying Facilities, 10
average megawatts in any given month. For wind and solar Qualifying Facilities, “Eligibility Cap”
means 100 kilowatts (“kW”) nameplate capacity.

Facility means the electric generation facility owned by the Customer that is located on the
Customer’s side of the POD, and all facilities ancillary and appurtenant thereto, including
interconnection equipment.

Heavy Load Hours means the daily hours from hour ending 0700 – 2200 Mountain Time, (16
hours) excluding all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

Light Load Hours means the daily hours from hour ending 2300 – 0600 Mountain Time, (8
hours) plus all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

Idaho Power Company Original Sheet No. 73-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-2

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

DEFINITIONS (continued)

Integration Charges means the Commission-approved integration charge applicable to any
intermittent generation resource, including but not limited to, wind and solar generation.

Generator Interconnection Agreement (“GIA”). The interconnection agreement that specifies
terms, conditions, and requirements of interconnecting to the Company electrical system, which will
include, but not be limited to, all requirements as specified by Schedule 72. If the Facility is not
interconnecting directly to the Company electrical system, the Facility will not have a GIA with the
Company but instead will have a similar agreement with the utility the Facility is directly interconnecting
to.

Point of Delivery (POD) is the location specified in the GIA (or Transmission Agreement) where
the Company’s and the Seller’s (or third-party transmission provider’s) electrical facilities are
interconnected and the energy from the Qualifying Facility is delivered to the Company electrical
system.

Qualifying Facility shall mean a Cogeneration Facility or a Small Power Production Facility that
is a “Qualifying Facility” as that term is defined in the Federal Energy Regulatory Commission’s
regulations, 18 C.F.R. § 292.101(b)(1) (2010), as may be amended or superseded.

Seasonal Factors means a seasonal weighting of 0.735 for the months of March, April, and
May, 1.20 for the months of July, August, November, and December and 1.00 for the months of
January, February, June, September, and October.

Small Power Production Facility means the equipment used to produce output including electric
energy solely by the use of biomass, waste, solar power, wind, water, or any other renewable resource.

Transmission Agreement. If the Facility is not directly interconnected to the Company electrical
system, the Facility must obtain firm transmission rights from the appropriate utility(s) to deliver the
Facility’s maximum capacity to an agreed to POD on the Company electrical system for the full term of
the ESA. This agreement(s) shall have minimum terms equal to the lesser of (a) the term of the ESA
being requested by the Qualifying Facility in Section 1.a.xiv., or (b) the minimum term required by the
third-party transmission entity to ensure firm roll over transmission rights, and (c) any other applicable
terms and conditions to ensure the Facility shall have firm transmission rights for the full term of the
ESA.

RATE OPTIONS

The Company is required to pay the following rates, at the election of the Qualifying Facility, for
the purchase of output from Facilities for which this tariff applies and that is delivered and accepted by
the Company in accordance with the ESA. These rates are adjusted periodically and are on file with
the Commission.

Idaho Power Company Original Sheet No. 73-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-3

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

RATES OPTIONS (Continued)

1. Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled with
fossil fuels and shall depend upon the on-line operation date and term of the agreement and shall be
fixed for the term. The adjustable component rate shall be changed periodically subject to Commission
orders. Both the fixed and adjustable rate components are subject to Seasonal Factors, a Daily Shape
Adjustment, and Integration Charges.

2. Non-Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Non-Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled
with fossil fuels and shall depend upon the on-line operation date and term of the agreement. The fixed
component rate shall be fixed for the term of the agreement. The adjustable component rate shall be
changed periodically subject to Commission orders. Both the fixed and adjustable rate components are
subject to Seasonal Factors, a Daily Shape Adjustment, and Integration Charges.

3. Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Non-Fueled Facilities. These rates shall apply to Facilities that
do not use fossil fuels as their primary fuel. The rates shall depend upon the on-line operation date and
term of the agreement and shall be fixed for the term. The rate components are subject to Seasonal
Factors, a Daily Shape Adjustment, and Integration Charges.

4. Non-Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects
at or below the Eligibility Cap when the Customer chooses to supply output including energy and
capacity under a contract based on Non-Levelized Avoided Cost Rates for Non-Fueled Facilities.
These rates shall apply to Facilities that do not use fossil fuels as their primary fuel, and shall be fixed
for the term. The rates are subject to a Seasonal Factor, a Daily Shape Adjustment, and Integration
Charges.

5. Rates Determined at the Time of Delivery. Please see the Company’s tariff Schedule
86.

6. Integrated Resource Plan (“IRP”) Based Rate. The IRP Based Rate is required for all
Qualifying Facilities that do not meet the Eligibility Cap and shall be calculated based on the
Incremental Cost IRP Methodology tailored to the individual characteristics of the proposed Qualifying
Facility.

CONTRACTING PROCEDURES

The Company agrees to adhere to the following contract procedures for the purchase of output
from Customers who own Qualifying Facilities for which this tariff applies and that is delivered to the
Company’s system. These contracting procedures are adjusted periodically and are on file with the
Commission.

Idaho Power Company Original Sheet No. 73-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures

a. To obtain an indicative pricing proposal for a proposed Qualifying Facility, the
Customer shall provide the Company a completed Qualifying Facility Energy Sales Agreement
Application utilizing the Application template included in this Schedule. The information required
within the application is general information as listed below.

i. Qualifying Facility owner name, organizational structure and chart, contact
information, and project name;

ii. Generation and other related technology applicable to the Qualifying
Facility;

iii. Maximum design capacity, station service requirements, and the net
amount of power, all in kW, to be delivered to the Company’s electric system by the
Qualifying Facility;

iv. Schedule of estimated Qualifying Facility electric output, in an 8,760-hour
electronic spreadsheet format;

v. Ability, if any, of Qualifying Facility to respond to dispatch orders from the
Company;

vi. Map of Qualifying Facility location, electrical interconnection point, and
POD (identified by nearest landmark and GPS coordinates);

vii. Anticipated commencement date for delivery of electric output;

viii. List of acquired and outstanding Qualifying Facility permits, including a
description of the status and timeline for acquisition of any outstanding permits;

ix. Demonstration of ability to obtain Qualifying Facility status;

x. Fuel type(s) and source(s);

xi. Plans to obtain, or actual fuel and transportation agreements, if
applicable;

xii. Where Qualifying Facility is or will be interconnected to an electrical
system besides the Company’s, plans to obtain, or actual electricity transmission
agreements with the interconnected system;

xiii. Interconnection agreement status; and
Idaho Power Company Original Sheet No. 73-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-5

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

xiv. Proposed contracting term and requested Rate Option for the sale of
electric output to the Company.

b. Where the Company determines that the Customer has not provided sufficient
information as required by Section 1.a., the Company shall, within 10 business days, notify the
Customer in writing of any deficiencies.

c. Following satisfactory receipt of all information required in Section 1.a., the
Company shall, within 20 business days, provide the Customer with an indicative pricing
proposal containing terms and conditions tailored to the individual characteristics of the
proposed Qualifying Facility; provided, however, that for Qualifying Facilities eligible for
Published Rates pursuant to the Commission’s eligibility requirements, the Company will
provide such indicative pricing proposal within 10 business days.

d. The indicative pricing proposal provided to the Customer pursuant to Section 1.c.
will not be final or binding on either party. Prices and other terms and conditions will become
final and binding on the parties under only two conditions:

i. The prices and other terms contained in an ESA shall become final and
binding upon full execution of such ESA by both parties and approval by the
Commission, or

ii. The applicable prices that would apply at the time a complaint is filed by a
Qualifying Facility with the Commission shall be final and binding upon approval of such
prices by the Commission and a final non-appealable determination by the Commission
that:

(a) a “legally enforceable obligation” has arisen and, but for the
conduct of the Company, there would be a contract, and
(b) the Qualifying Facility can deliver its electrical output within 365
days of such determination.

e. If the Customer desires to proceed with contracting its Qualifying Facility with the
Company after reviewing the indicative pricing proposal, it shall request in writing that the
Company prepare a draft ESA to serve as the basis for negotiations between the parties. In
connection with such request, the Customer shall provide the Company with any additional
Qualifying Facility information that the Company reasonably determines necessary for the
preparation of a draft ESA, which shall include:

i. Updated information of the categories described in Section 1.a.

ii. Evidence of site control for the entire contracting term
Idaho Power Company Original Sheet No. 73-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-6

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

iii. Anticipated timelines for completion of key Qualifying Facility milestones,
to include:

(a) Licenses, permits, and other necessary approvals;
(b) Funding;
(c) Qualifying Facility engineering and drawings;
(d) Significant equipment purchases;
(e) Construction agreement(s);
(f) Interconnection agreement(s); and
(g) Signing of third-party Transmission Agreements, where
applicable.

iv. Additional information as explained in the Company’s indicative pricing
proposal.

f. If the Company determines that the Customer has not provided sufficient
information as required by Section 1.e., the Company shall, within 10 business days, notify the
Customer in writing of any deficiency.

g. Following satisfactory receipt of all information required in Section 1.e., the
Company shall, within 15 business days, provide the Customer with a draft ESA containing a
comprehensive set of proposed terms and conditions. The draft shall serve as the basis for
subsequent negotiations between the parties and, unless clearly indicated, shall not be
construed as a binding proposal by the Company.

h. Within 90 calendar days after its receipt of the draft ESA from the Company
pursuant to Section 1.g., the Customer shall review the draft ESA and shall (a) notify the
Company in writing that it accepts the terms and conditions of the draft ESA and is ready to
execute an ESA with same or similar terms and conditions as the draft ESA or (b) prepare an
initial set of written comments and proposals based on the draft and provide them to the
Company. The Company shall not be obligated to commence negotiations with a Customer or
draft a final ESA unless or until the Company has timely received an initial set of written
comments and proposals from the Customer, or notice from the Customer that it has no such
comments or proposals, in accordance with this Section 1.h.

i. After Customer has met the provisions of Section 1.h. above, Customer shall
contact the Company to schedule ESA negotiations at such times and places as are mutually
agreeable to the parties.

Idaho Power Company Original Sheet No. 73-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-7

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

j. In connection with any ESA negotiations between the Company and the
Customer, the Company:

i. Shall not unreasonably delay negotiations and shall respond in good faith
to any additions, deletions, or modifications to the draft ESA that are proposed by the
Customer;

ii. May request to visit the site of the proposed Qualifying Facility;

iii. Shall update its pricing proposals at appropriate intervals to
accommodate any changes to the Company’s avoided cost calculations, the proposed
Qualifying Facility or proposed terms of the draft ESA;

iv. Shall include any revised contracting terms, standards, or requirements
that have occurred since the initial draft ESA was provided;

v. May request any additional information from the Customer necessary to
finalize the terms of the ESA and to satisfy the Company’s due diligence with respect to
the Qualifying Facility.

k. When both parties are in full agreement as to all terms and conditions of the draft
ESA, including the price paid for delivered energy, and the Customer provides evidence that
any applicable Transmission Agreements have been executed and/or execution is imminent, the
Company shall prepare and forward to the Customer, within 10 business days, a final,
executable version of the ESA.

l. The Customer shall, within 10 business days, execute and return the final ESA to
the Company.

m. Where the Customer timely executes and returns the final ESA to the Company
in accordance with Section 1.l. above, the Company will, within 10 business days of its receipt
of the ESA executed by the Customer, execute such ESA. The Company will then submit the
executed ESA to the Commission for its review.

n. Failure of the Customer to meet any timelines set forth in this section relieves the
Company of any obligation under this tariff until such time as the Customer resubmits its
Qualifying Facility and the procedures begin anew. If the Customer does not execute the final
ESA per Section 1.l, such final ESA shall be deemed withdrawn and the Company shall have
no further obligation to the Customer under this tariff unless or until such time the Customer
resubmits the Qualifying Facility to the Company in accordance with this Schedule.

Idaho Power Company Original Sheet No. 73-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-8

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – July 1, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

2. Interconnection, Transmission Agreements, and Designated Network Resource

a. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the consummation of a GIA in accordance with the
Company’s Schedule 72. Where the Qualifying Facility will not be physically located within the
Company’s electrical system, the Customer will need to consummate a similar GIA with the
third-party electrical system.

b. Where the Qualifying Facility will be interconnected to a third-party electrical
system and is requesting either Published Rates, or rates based on firm delivery of its electrical
output, the Company’s obligation to purchase such electrical output will be conditioned on the
Customer obtaining a firm Transmission Agreement or agreements to deliver all electrical output
to the agreed upon POD.

c. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the Facility being classified as a Company Designated
Network Resource.

3. Qualifying Facility Energy Sales Agreement Application

(FORM STARTS ON NEXT PAGE)
Idaho Power Company Original Sheet No. 73-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 73-9

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION

Idaho Power Qualifying Facility (QF) contact information:

Mailing Address: Attn: Energy Contracts, P O Box 70 Boise, ID 83702
Physical Address: 1221 W. Idaho Street, Boise, ID 83703
Telephone number: 208-388-6070
E-Mail Address: [e-mail]

Preamble and Instructions

All generation facilities that qualify pursuant to Idaho Power Company Schedule 73 for a QF Energy
Sales Agreement and wish to sell energy from their facility to Idaho Power must complete the following
information and submit this Application by hand delivery, mail or E-mail to Idaho Power.

Upon receipt of a complete Application, Idaho Power shall process this request for a QF Energy Sales
Agreement pursuant to Idaho Power Company Schedule 73.

Qualifying Facility Information

Proposed Project
Name of Facility:
Resource Type: (i.e. wind, solar, hydro, etc):
Facility Location: GPS Coordinates:
Nearest City or landmark:
County and State:
Map of Facility, including proposed interconnection point.
Anticipated commencement date of energy deliveries to Idaho Power:
Facility Nameplate Capacity Rating (kW):
Facility Maximum Output Capacity (kW):
Station Service Requirements (kW):
Facility Net Delivery to Idaho Power (kW):
Facility interconnection status:
Proposed Contracting Term (cannot exceed 20 years):
Requested Rate Option (details provided in Schedule 73):
Does the Facility have the ability to respond to dispatch
orders from Idaho Power Company (Yes or No):

Idaho Power Company Original Sheet No. 73-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 73-10

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION
(Continued)

Please include the following attachments:

 Hourly estimated energy deliveries (kW) to Idaho Power for every hour of a one year period.

 List of acquired and outstanding Qualifying Facility permits, including a description of the status
and timeline for acquisition of any outstanding permits.
 At the minimum a FERC issued QF certificate/self-certification is required and/or
evidence that Facility will be able to obtain a Qualifying Facility certificate.

 If the Facility will require fuel be transported to the Facility (i.e. natural gas pipelines, railroad
transportation, etc), evidence of ability to obtain sufficient transportation rights to operate the
Facility at the stated Maximum Output Amount.

 If the Facility will not be interconnecting directly to the Idaho Power electrical system, evidence
that the Facility will be able to interconnect to another utility’s electrical system and evidence
that the Facility will be able to obtain firm transmission rights over all required transmission
providers to deliver the Facility’s energy to Idaho Power.

Owner Information
Owner / Company Name:
Contact Person:
Address:
City: State: Zip:
Telephone:
E-mail:

Applicant Signature

I hereby certify that, to the best of my knowledge, all information provided in this Qualifying
Facility Energy Sales Agreement application is true and correct.

__________________________________________________________________
Signature

__________________________________________________________________
Print Name

________________________________________
Date
Idaho Power Company Original Sheet No. 79-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 79-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 79
WEATHERIZATION ASSISTANCE
FOR QUALIFIED CUSTOMERS

AVAILABILITY

Funding under this schedule is available to state designated Community Action Partnership
(CAP) agencies throughout the Company's service area within the State of Idaho participating in the
State of Idaho Weatherization Assistance Program administered by the Idaho Department of Health
and Welfare. Funding under this schedule is subject to the provisions of the signed Agreement
between the individual CAP agencies and the Company.

APPLICABILITY

Funding under this schedule is applicable to qualifying energy conservation measures installed
in single- and multi-family residential dwellings, including mobile homes, which are electrically heated
(Qualifying Dwellings). Funding is also applicable to qualifying energy conservation measures installed
in buildings which are occupied by private, non-profit organizations which serve primarily low-income
clientele, and which have obtained a 501(c)(3) tax exempt status (Qualifying Buildings). Energy
conservation measures installed in Qualifying Dwellings and Qualifying Buildings must meet the
specifications of the State of Idaho Weatherization Assistance Program.

GRANTS TO AGENCIES

The Company will determine the amount of annual grant funds available to each participating
CAP agency each year in accordance with the provisions of the Agreement. Funds will be distributed
to a participating CAP agency upon demonstration by the agency that qualifying conservation
measures have been installed in a Qualifying Dwelling or Qualifying Building. Grant funds made
available to a CAP agency but not distributed to that agency during the current year may be carried
forward to the next year.

In addition to weatherization funds, the Company will provide to each CAP agency an
administrative payment equal to 10 percent of the portion funded by the Company for each Qualifying
Dwelling or Qualifying Building for which weatherization was completed with the assistance of
Company funds.

Qualifying Dwellings: The Company grant funds may be used to fund up to 85 percent of the
total cost of qualifying conservation measures installed in a Qualifying Dwelling provided at least 15
percent of the total cost of qualifying conservation measures is funded by the Department of Energy,
except in the case where carryover funds are being used for re-weatherization. Re-weatherization
applies to homes that were previously weatherized under Schedule 79 within a rolling 14-year period.
For those homes, the program’s carryover funds may be used to pay up to 100 percent of HVAC
upgrades.

Qualifying Buildings: The Company grant funds may be used to fund the installation of
weatherization measures in Qualifying Buildings in accordance with the provisions of the Agreement.
The Company provided funds may be used to fund up to 100 percent of the total cost of qualifying
conservation measures installed in Qualifying Buildings.

Idaho Power Company Original Sheet No. 81-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 81-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)

PURPOSE

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

DEFINITIONS

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

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

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

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

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

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

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

Idaho Power Company Original Sheet No. 81-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 81-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

AVAILABILITY

Service under this schedule is available on an optional basis to Customers taking service under
Schedules 1, 5, or 6 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 Idaho 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. If 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.

Idaho Power Company Original Sheet No. 81-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 81-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

PROGRAM DESCRIPTION

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

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

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

SPECIAL CONDITIONS

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

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

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

The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer’s load for a system emergency in accordance with NERC standards, Idaho Power’s Rule J,
or any other time that a Customer’s service is interrupted by events outside the control of the Company.
The provisions of this schedule will not affect the calculation or rate of the regular Service or Energy
Charges associated with a Customer’s standard service schedule.
Idaho Power Company Original Sheet No. 82-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

PURPOSE

The Flex Peak Program (the Program) is a voluntary program that motivates Participants to
reduce their load during Company initiated Load Control Events or to allow the Company to send a signal
to automatically initiate a Load Control Event with the use of one or more Load Control Devices. A
participating Customer will be eligible to receive a financial incentive in exchange for being available to
reduce their load during the calendar months of June, July, August, and September.

AVAILABILITY

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

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

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

PROGRAM DESCRIPTION

The Company will initiate Load Control Events for a maximum of 60 hours during June, July,
August, and September. During Load Control Events, Participants will be expected to reduce load at their
Facility Site(s), and load reduction may be initiated manually or automatically depending on the
Interruption Option designated for the Facility Site(s). Participants will be eligible to receive a financial
incentive in exchange for their reduction in load.

DEFINITIONS

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

Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment
amount.
Idaho Power Company Original Sheet No. 82-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

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

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

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

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

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

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

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

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

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

Idaho Power Company Original Sheet No. 82-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

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

Notification of Program Acceptance. Written confirmation from the Company to the Participant
based on the Program Application Agreement submitted by the Customer. The Notification of Program
Acceptance will confirm each Facility Site enrolled in the Program, the initial Nominated kW amount for
each Facility Site, and the Interruption Option for each Facility Site.

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

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

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

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

Original 
Baseline 
(kW) 3367 3400 3350 3367 3433 3400 

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

Program Application/Agreement. Written form submitted by a Customer who requests to enroll
a Facility Site in the Program that is signed by the Customer or a duly authorized representative
certifying agreement with the Program’s terms and conditions.

Idaho Power Company Original Sheet No. 82-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

Program Week. Monday through Friday.

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

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

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

LOAD CONTROL EVENTS

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

INTERRUPTION OPTIONS

At the Participant’s election, and subject to Company discretion, participation in the Program may
occur via one of the following Interruption Options:

Manual Dispatch Option. Customers are eligible to manually control their Facility Site(s). Under
the Manual Dispatch Option customers have the flexibility to choose which loads will be interrupted during
each dispatched Load Control Event.

Automatic Dispatch Option. A dispatchable Load Control Device, provided and installed by the
Company or its representative, will be connected to the electrical panel(s) serving the loads associated
with the Facility Site(s) enrolled in the Program. The Load Control Device utilized under the Automatic
Dispatch Option will provide the Company the ability to send a signal intended to interrupt operation of a
particular load or service during dispatched Load Control Events. In lieu of the Company or its
representative installing the Load Control Device at the Company’s expense, the Participant may elect
to hire a licensed electrician, at the Participant’s expense, to install the Load Control Device in accordance
Idaho Power Company Original Sheet No. 82-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

INTERRUPTION OPTIONS (Continued)

with the National Electrical Code (“NEC”) and any Idaho Power or manufacturer specifications or
requirements.

REQUIREMENTS OF PARTICIPATING FACILITIES

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

INCENTIVE STRUCTURE

Incentive payments will be determined based on a Fixed Capacity Payment, a Variable Energy
Payment, and any applicable Nominated kW Incentive Adjustment. Both the Fixed Capacity and Variable
Energy Payments will be paid by check or bill credit no more than 45 days after the Program Season
concludes on September 15th.

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

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

For Load Control Events, the Nominated kW Incentive Adjustment will be $2.00 per kW for each
hour the Nominated kW is not achieved during that interval. The total Nominated kW Incentive
Adjustments will not exceed the total incentive amount for the Program Season. At its discretion, the
Company may waive all or a portion of an Incentive Adjustment should it be determined that, at no fault
of the customer, the Load Control Device utilized for the Automatic Dispatch Option did not work during
a Load Control Event.

Fixed Capacity Payment Rate*
(*to be prorated for partial weeks) Variable Energy Payment Rate*
(*does not apply to first four Load Control Events)

$3.25 per Weekly Effective kW Reduction

$0.20 per kWh
Idaho Power Company Original Sheet No. 82-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 82-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

TERMS AND CONDITIONS

Upon acceptance into the Program, Participants agree to the provisions of this Schedule and to
the following terms and conditions:

1. Once accepted into the Program, Participants will automatically be re-enrolled each year
thereafter unless notice of termination is given by the other party.

2. Both the Company and the Participant may terminate participation in the Program
at any time by notifying the other party in writing.

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

4. The Company retains the sole right to determine the criteria under which a Load Control
Event is called and the decision of whether to call for, initiate, or cancel a Load Control
Event shall be at the Company’s sole discretion.

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

6. Participants that choose to participate in the Program under the Automatic Dispatch
Option grant the Company or its representative permission, on reasonable notice, to enter
the Customer’s enrolled Facility Site(s) to install, service, maintain, and/or remove Load
Control Device(s) on the electrical panel that services the anticipated load reduction. The
Company retains the sole right for its employees and its representatives to install or not
install Load Control Devices on the Customer’s electrical panel at the time of installation
depending on, but not limited to, safety, reliability, or other issues that may not be in the
best interest of the Company, its employees, or its representatives.

7. If there is evidence of the Participant altering, tampering, or otherwise interfering with the
Company’s ability to initiate a Load Control Event, the Customer’s participation in the
Program will be terminated, and the Customer will be required to reimburse the Company
for all costs for replacement or repair of the Load Control Device(s) or other Program
equipment, including labor and other related costs, and the Company will reverse any and
all incentive payments made during the previous twelve months as a result of the
Customer’s participation in the Program.

Idaho Power Company Original Sheet No. 82-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 82-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

SPECIAL CONDITIONS

The Company is not responsible for any direct, indirect, consequential, incidental, punitive, or
exemplary damage to the Participant or third parties as a result of the Program or the Customer’s
voluntary participation in the Program.

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

The provisions of this Program do not apply for any time period that the Company requests a load
reduction during a system emergency in accordance with NERC standards, Idaho Power’s Rule J, or any
other time that a Customer’s service is interrupted by events outside the control of the Company. The
provisions of this Program will not affect the calculation or rate of the regular Service, Energy, or Demand
Charges associated with a Participant’s standard service schedule.
Idaho Power Company Original Sheet No. 84-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 84-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho for Customers intending to operate Exporting Systems to generate electricity to reduce all or part
of their monthly energy usage.

Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small
general service customers.

Effective December 2, 2020, Schedule 84 is closed to new applications with a two-meter
interconnection.

APPLICABILITY

Service under this schedule is applicable to any Customer that:

1. Does not take service under Schedule 5, Schedule 6, or Schedule 8; and

2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal,
or hydropower, or represents fuel cell technology; and

3. Maintains its retail electric service account for the loads served at the Point of Delivery
adjacent to the Generation Interconnection Point as active and in good standing; and

4. Meets all requirements applicable to Exporting Systems detailed in the Company’s
Schedule 68, Interconnections to Customer Distributed Energy Resources; and

5. Takes retail electric service under:

a. Schedule 1 or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25
kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the
Company is through the Company’s existing watt-hour retail meter.

b. Schedule 9, Schedule 19, or Schedule 24; and

i. Two Meter Interconnection (Closed to new applicants effective December
2, 2020): Owns and/or operates a Generation Facility with a total nameplate capacity
rating of 100 kW or smaller that is interconnected at a Generation Interconnection Point
that, at the Company’s discretion, is located either adjacent to or on the Customer’s side
of the Point of Delivery and is metered through a meter that is separate from the retail
load metering at the Customer’s Point of Delivery. A separate meter from the existing
retail load metering at the Customer’s Point of Delivery is not required if the Customer
meets the criteria below. The One Meter Option is available if:

Idaho Power Company Original Sheet No. 84-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

APPLICABILITY (Continued)

1. The Generation Facility has a total nameplate capacity rating of 25
kW or smaller; and

2. The Generation Facility has a total nameplate capacity rating that
is no more than 2% of the Customer’s Basic Load Capacity (BLC) or comparable
average maximum monthly Billing Demands.

ii. Single-Meter Interconnection (applicable to new applicants effective
December 2, 2020): Owns and/or operates a Generation Facility with a total nameplate
rating of 100 kW or smaller that is interconnected to the Customer’s individual electric
system on the Customer’s side of the Point of Delivery, thus all energy received and
delivered by the Company is through the Company’s existing watt-hour retail meter.

6. A Customer submitting a two-meter interconnection application for service under
Schedule 84 must complete the interconnection pursuant to the terms of Schedule 72 by December 1,
2021. Grandfather Status will terminate on December 1, 2045.

7. The Grandfather Status of the two-meter Generation Facility is transferable to a
subsequent Customer at the premises for which a valid Net Metering Service is in effect. Each
Customer of a Generation Facility taking service under Schedule 84 will be responsible for complying
with the terms and conditions of the Net Metering Service in effect for that premises.

8. A two-meter Generation Facility that is offline for over six (6) months or that is moved to
a different site shall forfeit Grandfather Status of the Generation Facility.

9. To remain eligible for Grandfather Status, a Customer may increase the capacity of a
grandfathered Generation Facility by no more than 10 percent of the originally installed nameplate
capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded
components. If a Customer expands a grandfathered Generation Facility beyond these limits, the new
portion of the Generation Facility would not qualify for Grandfather Status.

10. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the
Grandfathered Status of the Generation Facility.

Idaho Power Company Original Sheet No. 84-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

DEFINITIONS

Basic Load Capacity (BLC) is the average of the two greatest non-zero monthly Billing Demands
established during the 12-month period which includes and ends with the current Billing Period.

Designated Meter is the retail meter physically connected to the Exporting System.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is either delivered to the Company via a single meter at the Point of Delivery or Generation
Interconnection Point, or is consumed by the Customer.

Generation Interconnection Point is the point where the conductors installed to allow receipt of the
Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery.

Grandfathered Status refers to the ability for a system to receive the compensation structure in
place on December 1, 2020. The compensation structure applicable to systems with a Grandfather
Status includes net monthly one-for-one kWh credit compensation for Excess Net Energy.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery or Generation Interconnection Point.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

Idaho Power Company Original Sheet No. 84-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

MONTHLY BILLING

The Customer shall be billed in accordance with the Customer’s applicable standard service
schedule, including appropriate monthly charges.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period,
the Customer shall be billed for the net electricity supplied by the Company at the Customer’s
standard schedule retail rate, in accordance with normal metering practices.

b. Effective at the beginning of each Customer’s January 2014 Billing Period, if
electricity generated by the Customer and delivered to the Company during the Billing Period
exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy
shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period.
Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers
shall be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end
of the Customer’s December Billing Period the Customer may request to transfer the unused
credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it
meets all of the following criteria:

i. The account subject to offset is held by the Customer; and

Idaho Power Company Original Sheet No. 84-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 84-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

iii. The meter is served by the same primary feeder as the Designated Meter
at the time the Customer files the application for the Exporting System; and

iv. The electricity recorded by the meter is for the Customer’s requirements;
and

v. For Customers taking service under Schedule 1 or Schedule 7, credits may
only be transferred to meters taking service under Schedule 1 or Schedule 7. For
Customers taking service under Schedule 9, Schedule 19, or Schedule 24, credits may
only be transferred to meters taking service under Schedule 9, Schedule 19, or Schedule
24.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by
midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer
Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will
carry forward to offset consumption at the Designated Meter until they become eligible for transfer
on January 1 of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the
Company no later than March 31. Transfers will be based on the balance of Excess Net Energy
credits available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v)
above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any
reason.

Idaho Power Company Original Sheet No. 84-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of a Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of
electricity in the same manner and to the same degree as other Customers on the Company’s standard
service schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the
purpose of installation, operation, maintenance, replacement or any other service required of said
equipment, as well as all necessary access for inspection, switching and any other operational
requirements of the Customer’s Interconnection Facilities.

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this
schedule is any removal or disablement of an Exporting System lasting longer than six (6) months.
Customers with permanently removed systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

Idaho Power Company Original Sheet No. 86-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 86-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho.

APPLICABILITY

Service under this schedule is applicable to any Seller that:

1. Owns or operates a Qualifying Facility with a nameplate capacity rating of less than 10
MW and desires to sell Energy generated by the Qualifying Facility to the Company on a non-firm, if, as,
and when available basis;

2. Meets all applicable requirements of the Company’s Schedule 72 and the Generation
Interconnection Process.

DEFINITIONS

Avoided Energy Cost is 82.4% of the monthly arithmetic average of each day’s Intercontinental
Exchange (“ICE”) daily firm Mid-C Peak Avg and Mid-C Off-Peak Avg index prices. Each day’s index
prices will reflect the relative proportions of peak hours and off-peak hours in the month as follows:

Heavy Load (HL) Hours: The daily hours from hour ending 0700-2200 Mountain
Time, (16 hours) excluding all hours on all Sundays, New Years Day, Memorial
Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.

Light Load (LL) Hours: The daily hours from hour ending 2300-0600 Mountain
Time (8 hours), plus all other hours on all Sundays, New Years Day, Memorial
Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.
The actual Avoided Energy Cost calculation being:
n
.824 * ( ∑ {(ICE Mid-C Peak Avgx * HL hours for day) + X=1
(ICE Mid-C Off-Peak Avgx * LL hours for day)} / (n*24))
where n = number of days in the month

If the ICE Mid-C Index prices are not reported for a particular day or days, prices derived from the
respective averages of HL and LL prices for the immediately preceding and following reporting periods or
days shall be substituted into the formula stated in this definition and shall therefore be multiplied by the
appropriate respective numbers of HL and LL Hours for such particular day or days with the result that
each hour in such month shall have a related price in such formula. If the day for which prices are not
reported has in it only LL Hours (for example a Sunday), the respective averages shall use only prices
reported for LL hours in the immediately preceding and following reporting periods or days. If the day for
which prices are not reported is a Saturday or Monday or is adjacent on the calendar to a holiday, the
prices used for HL Hours shall be those for HL hours in the nearest (forward or backward) reporting
periods or days for which HL prices are reported.
Idaho Power Company Original Sheet No. 86-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 86-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

DEFINITIONS (Continued)

Designated Dispatch Facility is the Company's Boise Bench Dispatch Center.

Energy means the non-firm electric energy, expressed in kWh, generated by the Qualifying
Facility and delivered by the Seller to the Company in accordance with the conditions of this schedule.
Energy is measured net of Losses and Station Use.

Generation Facility means equipment used to produce electric energy at a specific physical
location, which meets the requirements to be a Qualifying Facility.

Generation Interconnection Process is the Company’s generation interconnection application and
engineering review process developed to ensure a safe and reliable generation interconnection.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the National Electric Safety Code to interconnect and safely deliver Energy from the Qualifying Facility to
the Company's system, including, but not limited to, connection, transformation, switching, metering,
relaying, communications, disconnection, and safety equipment.

Losses are the loss of electric energy occurring as a result of the transformation and transmission
of electric energy from the Qualifying Facility to the Point of Delivery.

Point of Delivery is the location where the Company's and the Seller's electrical facilities are inter-
connected.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of the
Code of Federal Regulations.

Schedule 72 is the Company's service schedule which provides for interconnection to non-utility
generation or its successor schedule(s) as approved by the Commission.

Seller is any entity that owns or operates a Qualifying Facility and desires to sell Energy to the
Company.

Idaho Power Company Original Sheet No. 86-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 86-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

DEFINITIONS (Continued)

Standby Power is electrical energy or capacity supplied by the Company during an unscheduled
outage of a Qualifying Facility to replace energy consumed by the seller which is ordinarily supplied by
the Seller's Qualifying Facility.

Station Use is electric energy used to operate the Qualifying Facility which is auxiliary to or directly
related to the generation of electricity and which, but for the generation of electricity, would not be
consumed by the Seller.

Supplementary Power is electric energy or capacity supplied by the Company which is regularly
used by a Seller in addition to the Energy and capacity which the Qualifying Facility usually supplies to
the Seller.

PURCHASE PRICE

The Company will pay the Seller monthly, for each kWh of Energy delivered and accepted at the
Point of Delivery during the preceding calendar month, an amount equal to 85 percent of the monthly
Avoided Energy Cost.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. The Company shall purchase Energy from any Seller that offers to sell Energy to the
Company.

2. As a condition of interconnection with the Company, the Seller shall:

a. Complete and maintain all requirements of interconnection in accordance with
Schedule 72.

b. Complete and maintain all requirements of the Company’s Generation
Interconnection Process.

c. Submit proof to the Company of all insurance required by paragraph 12.

d. Obtain written confirmation from the Company that all conditions to
interconnection have been fulfilled prior to operation of the Generation Facility. Such
confirmation shall not be unreasonably withheld by the Company.

Idaho Power Company Original Sheet No. 86-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 86-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

3. The Seller shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Seller’s Generation Facility is de-energized for any reason.

4. The Seller and the Company shall each indemnify the other, their respective officers,
agents, and employees against all loss, damage, expense, and liability to third persons for injury to or
death of persons or injury to property, proximately caused by the indemnifying party's construction,
ownership, operation or maintenance of, or by failure of, any of such party's works or facilities used in
connection with purchases under this schedule. The indemnifying party shall, on the other party's
request, defend any suit asserting a claim covered by this indemnity. The indemnifying party shall pay
all costs that may be incurred by the other party in enforcing this indemnity.

5. The Company shall offer to provide Standby Power and Supplementary Power to the
Seller. Charges for Supplementary and Standby Power will be in accordance with the Company's
Schedule 7 as that schedule is modified from time to time by the Commission.

6. The Seller shall maintain voltage levels acceptable to the Company.

7. The Seller shall maintain at the Qualifying Facility or such other location mutually
acceptable to the Company and Seller, adequate metering and related power production records, in a
form and content recommended by the Company.

Either the Seller or the Company after reasonable notice to the other party, shall have the right,
during normal business hours, to inspect and audit any or all such metering and related power
production records pertaining to the Seller’s account.

8. During a period of shortage of energy on the Company's system, the Seller shall, at the
Company's request and within the limits of reasonable safety requirements as determined by the Seller,
use its best efforts to provide requested Energy, and shall, if necessary, delay any scheduled shutdown
of the Qualifying Facility.

9. The Company and the Seller shall maintain appropriate operating communications
through the Designated Dispatch Facility.

10. The Company shall not be obligated to accept, and the Company may require the Seller
to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent Electrical
Practices, determines that curtailment, interruption or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.

Idaho Power Company Original Sheet No. 86-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 86-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

11. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its Customers, the Company may require the Seller to curtail its consumption of electricity
in the same manner and to the same degree as other Customers within the same Customer class who
do not own Generation Facilities.

12. The Seller shall secure and continuously carry liability insurance coverage for both
bodily injury and property damage liability in the amount of not less than $1,000,000 each occurrence
combined single limit.

Such insurance shall include an endorsement naming the Company as an additional insured
insofar as liability arising out of operations under this schedule and a provision that such liability policies
shall not be canceled or their limits of liability reduced without 30 days' written notice to the Company.
The Seller shall furnish the Company with certificates of insurance together with the endorsements
required herein. The Company shall have the right to inspect the original policies of such insurance.

13. The Seller shall grant to the Company all necessary rights of way and easements to
install, operate, maintain, replace, and remove the Company's metering and other Interconnection
Facilities including adequate and continuing access rights to the property of the Seller. The Seller
warrants that it has procured sufficient easements and rights of way from third parties as are necessary
to provide the Company with the access described above. The Seller shall execute such other grants,
deeds, or documents as the Company may require to enable it to record such rights of way and
easements.

14. Depending on the size and location of the Seller's Qualifying Facility, it may be
necessary for the Company to establish additional requirements for operation of the Qualifying Facility.
These requirements may include, but are not limited to, voltage, reactive, or operating requirements.

Idaho Power Company Original Sheet No. 86-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 86-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

Idaho Power Company
For the Purchase of Non-Firm
Energy From Qualifying Facilities

THIS AGREEMENT Made this day of , 20 ,
between _______________________________________________________whose mailing address is
______________________________hereinafter called Seller and Idaho Power Company, a corporation
with its principal office located at 1221 West Idaho Street, Boise, Idaho hereinafter called "Company".

NOW, THEREFORE, The parties agree as follows:

1. Company shall purchase Energy produced by the Seller's Qualifying Facility located at or
near, ___________________County of , State of Idaho, located in the
_________ of Section ________, Township, _______ Range , BM, in the form of three phase
60 Hz and at a nominal phase to phase potential of volts, subject to emergency operating
conditions of the Company. Purchases under this Agreement are subject to the Company's applicable
Tariff provisions, including but not limited to Schedules 86 and 72 approved by and as may be hereafter
modified by the Idaho Public Utilities Commission ("Commission") and the provisions of this Agreement.

2. Seller shall pay Company for all costs of Interconnection Facilities as provided for in
Exhibit A of this Agreement and Schedule 72.

3. In addition to the charges provided under Paragraph 2, Seller shall pay to the Company
the monthly Operation & Maintenance Charge specified in Schedule 72 on the investment by the
Company in Interconnection Facilities which investment is set forth in Exhibit A, attached hereto and
made a part hereof. As such investment changes, in order to provide facilities to serve Seller’s
requirements, Company shall notify Seller in writing of additions or deletions of facilities by forwarding a
dated revised Exhibit A, which shall become part of this Agreement. The monthly Operation &
Maintenance Charge will be adjusted to correspond to the Revised Exhibit A.

4. The initial date of acceptance of Energy under this Agreement is subject to the Company's
ability to obtain required labor, materials, equipment, satisfactory rights of way, and comply with
governmental regulations.

5. The term of this Agreement shall become effective on the date first above written, and
shall continue to full force and effect until canceled by Seller upon sixty (60) days prior written notice.

6. 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 Commission and such other
administrative bodies having jurisdiction.

Idaho Power Company Original Sheet No. 86-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 86-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

Idaho Power Company
For the Purchase of Non-Firm
Energy From Qualifying Facilities
(Continued)

7. Nothing herein shall be construed as limiting the Commission from changing any rates,
charges, classification or service, or any rules, regulation or conditions relating to service under this
Agreement, or construed as affecting the right of the Company or the Seller to unilaterally make
application to the Commission for any such change.

8. This Agreement shall not become effective until the Commission approves all terms and
provisions hereof without change or condition and declares that all payments to be made hereunder
shall be allowed as prudently incurred expenses for rate making purposes.

(APPROPRIATE SIGNATURES)

Idaho Power Company Original Sheet No. 87-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES

APPLICABILITY

This schedule is applicable to all qualifying facility (“QF”) generators interconnected to the
Company that have generation of an intermittent nature, such as wind and solar generation. The initial
charges within this schedule are to be assessed to intermittent generation based upon the total
nameplate capacity of a specific type of intermittent generation interconnected to Company’s system.

The appropriate charges within this schedule will be included in all QF contracts, both published
and negotiated, at the time those contracts are executed and, once added, shall remain unchanged in
the contract for its duration. Subsequent changes to the charges within this schedule will only apply to
new QF contracts at the time those contracts are executed.

PART 1 – WIND INTEGRATION CHARGES

The following tables are applicable to all QF wind generation contracts that come online after
October 10, 2014:

Continued on next page
Idaho Power Company Original Sheet No. 87-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

601 - 700 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 14.94 2014 11.99
2015 15.39 2015 12.35
2016 15.85 2016 12.72
2017 16.33 2017 13.10
2018 16.82 2018 13.50
2019 17.32 2019 13.90
2020 14.32
2021 14.75
2022 15.19
2023 15.65
2024 16.12
2025 16.60
2026 17.10
2027 17.61
2028 18.14
2029 18.68
2030 19.24
2031 19.82
2032 20.42
2033 21.03
2034 21.66
2035 22.31
2036 22.98
2037 23.67
2038 24.38
2039 25.11

Idaho Power Company Original Sheet No. 87-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

701 - 800 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 19.38 2014 15.55
2015 19.96 2015 16.02
2016 20.56 2016 16.50
2017 21.17 2017 17.00
2018 21.81 2018 17.51
2019 22.46 2019 18.03
2020 18.57
2021 19.13
2022 19.70
2023 20.29
2024 20.90
2025 21.53
2026 22.18
2027 22.84
2028 23.53
2029 24.23
2030 24.96
2031 25.71
2032 26.48
2033 27.27
2034 28.09
2035 28.93
2036 29.80
2037 30.70
2038 31.62
2039 32.57

Idaho Power Company Original Sheet No. 87-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

801 - 900 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 24.34 2014 19.54
2015 25.07 2015 20.13
2016 25.83 2016 20.73
2017 26.60 2017 21.35
2018 27.40 2018 21.99
2019 28.22 2019 22.65
2020 23.33
2021 24.03
2022 24.75
2023 25.50
2024 26.26
2025 27.05
2026 27.86
2027 28.70
2028 29.56
2029 30.44
2030 31.36
2031 32.30
2032 33.27
2033 34.26
2034 35.29
2035 36.35
2036 37.44
2037 38.56
2038 39.72
2039 40.91

Idaho Power Company Original Sheet No. 87-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

901 - 1000 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 29.82 2014 23.94
2015 30.72 2015 24.66
2016 31.64 2016 25.40
2017 32.59 2017 26.16
2018 33.57 2018 26.94
2019 34.57 2019 27.75
2020 28.59
2021 29.44
2022 30.33
2023 31.24
2024 32.17
2025 33.14
2026 34.13
2027 35.16
2028 36.21
2029 37.30
2030 38.42
2031 39.57
2032 40.76
2033 41.98
2034 43.24
2035 44.54
2036 45.87
2037 47.25
2038 48.66
2039 50.12

Idaho Power Company Original Sheet No. 87-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

1001 - 1100 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 35.81 2014 28.74
2015 36.88 2015 29.60
2016 37.99 2016 30.49
2017 39.13 2017 31.41
2018 40.30 2018 32.35
2019 41.51 2019 33.32
2020 34.32
2021 35.35
2022 36.41
2023 37.50
2024 38.63
2025 39.78
2026 40.98
2027 42.21
2028 43.47
2029 44.78
2030 46.12
2031 47.51
2032 48.93
2033 50.40
2034 51.91
2035 53.47
2036 55.07
2037 56.72
2038 58.43
2039 60.18

Idaho Power Company Original Sheet No. 87-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

1101 - 1200 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 42.27 2014 33.93
2015 43.54 2015 34.95
2016 44.85 2016 36.00
2017 46.19 2017 37.08
2018 47.58 2018 38.19
2019 49.01 2019 39.34
2020 40.52
2021 41.73
2022 42.98
2023 44.27
2024 45.60
2025 46.97
2026 48.38
2027 49.83
2028 51.33
2029 52.87
2030 54.45
2031 56.09
2032 57.77
2033 59.50
2034 61.29
2035 63.12
2036 65.02
2037 66.97
2038 68.98
2039 71.05

Idaho Power Company Original Sheet No. 87-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

PART 2 – SOLAR INTEGRATION CHARGES

The following tables are applicable to all QF solar generation contracts that come online after February
11, 2015:

Continued on next page

Idaho Power Company Original Sheet No. 87-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

0 - 100 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.04 2016 0.04
2017 0.04 2017 0.04
2018 0.04 2018 0.04
2019 0.05 2019 0.04
2020 0.05 2020 0.04
2021 0.05 2021 0.04
2022 0.04
2023 0.04
2024 0.04
2025 0.04
2026 0.04
2027 0.05
2028 0.05
2029 0.05
2030 0.05
2031 0.05
2032 0.05
2033 0.05
2034 0.05
2035 0.05
2036 0.06
2037 0.06
2038 0.06
2039 0.06
2040 0.06
2041 0.06

Idaho Power Company Original Sheet No. 87-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

101 - 200 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.19 2016 0.16
2017 0.20 2017 0.17
2018 0.20 2018 0.17
2019 0.21 2019 0.18
2020 0.21 2020 0.18
2021 0.22 2021 0.18
2022 0.19
2023 0.19
2024 0.20
2025 0.20
2026 0.20
2027 0.21
2028 0.21
2029 0.22
2030 0.22
2031 0.23
2032 0.23
2033 0.24
2034 0.24
2035 0.25
2036 0.25
2037 0.26
2038 0.27
2039 0.27
2040 0.28
2041 0.28

Idaho Power Company Original Sheet No. 87-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

201 - 300 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.41 2016 0.34
2017 0.42 2017 0.35
2018 0.43 2018 0.36
2019 0.44 2019 0.37
2020 0.44 2020 0.38
2021 0.45 2021 0.38
2022 0.39
2023 0.40
2024 0.41
2025 0.42
2026 0.43
2027 0.44
2028 0.45
2029 0.46
2030 0.47
2031 0.48
2032 0.49
2033 0.50
2034 0.51
2035 0.52
2036 0.53
2037 0.54
2038 0.56
2039 0.57
2040 0.58
2041 0.59

Idaho Power Company Original Sheet No. 87-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

301 - 400 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED

ON-LINE
YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.64 2016 0.54
2017 0.65 2017 0.55
2018 0.67 2018 0.56
2019 0.68 2019 0.57
2020 0.70 2020 0.59
2021 0.71 2021 0.60
2022 0.61
2023 0.63
2024 0.64
2025 0.66
2026 0.67
2027 0.68
2028 0.70
2029 0.71
2030 0.73
2031 0.75
2032 0.76
2033 0.78
2034 0.80
2035 0.81
2036 0.83
2037 0.85
2038 0.87
2039 0.89
2040 0.91
2041 0.93

Idaho Power Company Original Sheet No. 87-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

401 - 500 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.84 2016 0.71
2017 0.86 2017 0.73
2018 0.88 2018 0.75
2019 0.90 2019 0.76
2020 0.92 2020 0.78
2021 0.94 2021 0.80
2022 0.81
2023 0.83
2024 0.85
2025 0.87
2026 0.89
2027 0.91
2028 0.93
2029 0.95
2030 0.97
2031 0.99
2032 1.01
2033 1.03
2034 1.06
2035 1.08
2036 1.10
2037 1.13
2038 1.15
2039 1.18
2040 1.20
2041 1.23

Idaho Power Company Original Sheet No. 87-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

501 - 600 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.01 2016 0.86
2017 1.03 2017 0.87
2018 1.06 2018 0.89
2019 1.08 2019 0.91
2020 1.10 2020 0.93
2021 1.13 2021 0.95
2022 0.97
2023 1.00
2024 1.02
2025 1.04
2026 1.06
2027 1.09
2028 1.11
2029 1.13
2030 1.16
2031 1.19
2032 1.21
2033 1.24
2034 1.26
2035 1.29
2036 1.32
2037 1.35
2038 1.38
2039 1.41
2040 1.44
2041 1.47

Idaho Power Company Original Sheet No. 87-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 87-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

601 - 700 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.12 2016 0.95
2017 1.15 2017 0.97
2018 1.17 2018 0.99
2019 1.20 2019 1.01
2020 1.22 2020 1.03
2021 1.25 2021 1.06
2022 1.08
2023 1.10
2024 1.13
2025 1.15
2026 1.18
2027 1.20
2028 1.23
2029 1.26
2030 1.29
2031 1.31
2032 1.34
2033 1.37
2034 1.40
2035 1.43
2036 1.46
2037 1.50
2038 1.53
2039 1.56
2040 1.60
2041 1.63

Idaho Power Company Original Sheet No. 87-16
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

701 - 800 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.17 2016 0.99
2017 1.20 2017 1.01
2018 1.22 2018 1.03
2019 1.25 2019 1.06
2020 1.28 2020 1.08
2021 1.30 2021 1.10
2022 1.13
2023 1.15
2024 1.18
2025 1.20
2026 1.23
2027 1.26
2028 1.28
2029 1.31
2030 1.34
2031 1.37
2032 1.40
2033 1.43
2034 1.46
2035 1.49
2036 1.53
2037 1.56
2038 1.60
2039 1.63
2040 1.67
2041 1.70

Idaho Power Company Original Sheet No. 87-17
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

801 - 900 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.16 2016 0.98
2017 1.19 2017 1.00
2018 1.21 2018 1.03
2019 1.24 2019 1.05
2020 1.27 2020 1.07
2021 1.30 2021 1.09
2022 1.12
2023 1.14
2024 1.17
2025 1.19
2026 1.22
2027 1.25
2028 1.28
2029 1.30
2030 1.33
2031 1.36
2032 1.39
2033 1.42
2034 1.45
2035 1.48
2036 1.52
2037 1.55
2038 1.59
2039 1.62
2040 1.66
2041 1.69

Idaho Power Company Original Sheet No. 87-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

901 - 1000 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.12 2016 0.94
2017 1.14 2017 0.96
2018 1.17 2018 0.99
2019 1.19 2019 1.01
2020 1.22 2020 1.03
2021 1.25 2021 1.05
2022 1.08
2023 1.10
2024 1.12
2025 1.15
2026 1.17
2027 1.20
2028 1.23
2029 1.25
2030 1.28
2031 1.31
2032 1.34
2033 1.37
2034 1.40
2035 1.43
2036 1.46
2037 1.49
2038 1.52
2039 1.56
2040 1.59
2041 1.63

Idaho Power Company Original Sheet No. 87-19
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1001 - 1100 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.06 2016 0.90
2017 1.08 2017 0.92
2018 1.11 2018 0.94
2019 1.13 2019 0.96
2020 1.16 2020 0.98
2021 1.18 2021 1.00
2022 1.02
2023 1.04
2024 1.07
2025 1.09
2026 1.11
2027 1.14
2028 1.16
2029 1.19
2030 1.22
2031 1.24
2032 1.27
2033 1.30
2034 1.33
2035 1.36
2036 1.39
2037 1.42
2038 1.45
2039 1.48
2040 1.51
2041 1.54

Idaho Power Company Original Sheet No. 87-20
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1101 - 1200 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.03 2016 0.87
2017 1.05 2017 0.89
2018 1.08 2018 0.91
2019 1.10 2019 0.93
2020 1.12 2020 0.95
2021 1.15 2021 0.97
2022 0.99
2023 1.01
2024 1.04
2025 1.06
2026 1.08
2027 1.11
2028 1.13
2029 1.16
2030 1.18
2031 1.21
2032 1.23
2033 1.26
2034 1.29
2035 1.32
2036 1.35
2037 1.37
2038 1.41
2039 1.44
2040 1.47
2041 1.50

Idaho Power Company Original Sheet No. 87-21
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1201 - 1300 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.07 2016 0.90
2017 1.09 2017 0.92
2018 1.12 2018 0.94
2019 1.14 2019 0.97
2020 1.17 2020 0.99
2021 1.19 2021 1.01
2022 1.03
2023 1.05
2024 1.08
2025 1.10
2026 1.12
2027 1.15
2028 1.17
2029 1.20
2030 1.23
2031 1.25
2032 1.28
2033 1.31
2034 1.34
2035 1.37
2036 1.40
2037 1.43
2038 1.46
2039 1.49
2040 1.52
2041 1.56

Idaho Power Company Original Sheet No. 87-22
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1301 - 1400 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.24 2016 1.05
2017 1.27 2017 1.07
2018 1.30 2018 1.10
2019 1.33 2019 1.12
2020 1.36 2020 1.15
2021 1.39 2021 1.17
2022 1.20
2023 1.22
2024 1.25
2025 1.28
2026 1.31
2027 1.33
2028 1.36
2029 1.39
2030 1.42
2031 1.46
2032 1.49
2033 1.52
2034 1.55
2035 1.59
2036 1.62
2037 1.66
2038 1.70
2039 1.73
2040 1.77
2041 1.81

Idaho Power Company Original Sheet No. 87-23
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1401 - 1500 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.61 2016 1.36
2017 1.65 2017 1.39
2018 1.69 2018 1.42
2019 1.72 2019 1.46
2020 1.76 2020 1.49
2021 1.80 2021 1.52
2022 1.55
2023 1.59
2024 1.62
2025 1.66
2026 1.70
2027 1.73
2028 1.77
2029 1.81
2030 1.85
2031 1.89
2032 1.93
2033 1.97
2034 2.02
2035 2.06
2036 2.11
2037 2.15
2038 2.20
2039 2.25
2040 2.30
2041 2.35

Idaho Power Company Original Sheet No. 87-24
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 87-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1501 - 1600 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 2.26 2016 1.91
2017 2.31 2017 1.95
2018 2.36 2018 2.00
2019 2.41 2019 2.04
2020 2.47 2020 2.09
2021 2.52 2021 2.13
2022 2.18
2023 2.23
2024 2.28
2025 2.33
2026 2.38
2027 2.43
2028 2.48
2029 2.54
2030 2.59
2031 2.65
2032 2.71
2033 2.77
2034 2.83
2035 2.89
2036 2.95
2037 3.02
2038 3.09
2039 3.15
2040 3.22
2041 3.29

Idaho Power Company Original Sheet No. 89-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 89-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 89
UNIT AVOIDED ENERGY COST
FOR COGENERATION AND SMALL
POWER PRODUCTION

AVAILABILITY

Service under this schedule is available in the service area of Idaho Power Company in the State
of Idaho.

APPLICABILITY

Service under this schedule is applicable to any Seller who owns or operates a Qualifying Facility
supplying the Company with both Capacity and Energy under Option 3 or 4 of a Power Sales Agreement.

DEFINITIONS

Capacity means the ability of the facility to generate electric power, expressed in kW, less station
use and less step-up transformation losses to the high voltage bus at the generator site.

Cogeneration Facility means equipment used to produce electric energy and forms of useful
thermal energy (such as heat or steam), used for industrial, commercial, heating or cooling purposes,
through the sequential use of energy.

Company means the Idaho Power Company.

Qualifying Facility or Facility means a Cogeneration Facility or a Small Power Production Facility
which meets the criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title
18, of the Code of Federal Regulations.

Seller as used herein means any individual, partnership, corporation, association, governmental
agency, political subdivision, municipality or other entity that owns or operates a Qualifying Facility.

Small Power Production Facility means the equipment used to produce electric energy solely by
the use of biomass, waste, solar power, wind or any other renewable resource.

MONTHLY PAYMENTS

The Company will compensate the Seller for the energy delivered and accepted each month
under the terms of the Power Sales Agreement at the following rate:

4.133¢ per kWh for all kWh

Idaho Power Company Original Sheet No. 91-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Tenth Revised Sheet No. 91-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 91
ENERGY EFFICIENCY RIDER

APPLICABILITY

This schedule is applicable to all retail Customers served under the Company’s schedules and
special contracts. This Energy Efficiency Rider is designed to fund the Company’s expenditures for the
analysis and implementation of energy conservation and demand response programs.

MONTHLY CHARGE

The Monthly Charge is equal to the applicable Energy Efficiency Rider percentage times the
sum of the monthly billed charges for the base rate components.

Schedule Energy Efficiency Rider

Schedule 1 2.35%
Schedule 3 2.35%
Schedule 5 2.35%
Schedule 6 2.35%
Schedule 7 2.35%
Schedule 8 2.35%
Schedule 9 2.35%
Schedule 15 2.35%
Schedule 19 2.35%
Schedule 20 2.35%
Schedule 24 2.35%
Schedule 40 2.35%
Schedule 41 2.35%
Schedule 42 2.35%
Schedule 26 2.35%
Schedule 29 2.35%
Schedule 30 2.35%
Schedule 32 2.35%
Schedule 33 2.35%
Schedule 34 2.35%

Idaho Power Company Original Sheet No. 95-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twelfth Revised Sheet No. 95-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 95
ADJUSTMENT FOR MUNICIPAL
FRANCHISE FEES

PURPOSE

The purpose of this schedule is to set forth the charges such as license, privilege, franchise,
business, occupation, operating, excise, sales or use of street taxes or other charges imposed on the
Company by municipal corporations and billed separately by the Company to its Customers within the
corporate limits of a municipality pursuant to Idaho Code § 50-329A.

APPLICABILITY

This schedule is applicable to all bills for Electric Service calculated under the Company’s
schedules and special Contracts in the Company’s service area within the State of Idaho as provided in
Rule C of this Tariff.

CHARGE

The rates and charges for Electric Service provided under the Company’s schedules will be
proportionately increased by the following charge within the municipality on and after the effective date
of the charge for the applicable municipal ordinance, which charge will be separately stated on the
Customer’s regular billing.

Effective Date
Municipality Ordinance No. Of Charge Charge

City of Aberdeen 303 July 31, 2015 1%
City of American Falls 659 September 28, 2023 1%
City of Bellevue 2008-06 February 28, 2008 3%
City of Blackfoot 2133 October 1, 2015 1%
City of Bliss 13-71 September 26, 2013 1%
City of Boise 6820 October 1, 2012 1.5%
City of Buhl 1013 November 20, 1997 1%
City of Caldwell 2133 June 26, 1996 1%
City of Cambridge 7-2020 January 29, 2021 1%
City of Carey 2017-02 September 28, 2017 1%
City of Cascade 712 November 16, 1995 1%
City of Chubbuck 498 January 21, 1999 1%
City of Council 362 September 1, 2000 1%
City of Crouch 2019-09 May 28, 2020 1%
City of Dietrich 2007-1 September 27, 2007 1%
City of Donnelly 231 August 30, 2016 1%
City of Eagle 514 December 29, 2010 1%
City of Eden 2015-3 November 2, 2015 1%
City of Emmett 858 June 26, 1996 1%

Idaho Power Company Original Sheet No. 95-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Twenty-Fourth Revised Sheet No. 95-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 95
ADJUSTMENT FOR MUNICIPAL
FRANCHISE FEES
(Continued)

CHARGE (Continued)

Effective Date
Municipality Ordinance No. Of Charge Charge

City of Fairfield 291 August 29, 2013 1%
City of Filer 574 September 30, 2009 2%
City of Fruitland 393 March 21, 2001 1%
City of Garden City 850-06 September 27, 2006 3%
City of Glenns Ferry 452 March 24, 1999 1%
City of Gooding 689 December 2, 2014 1%
City of Grand View 2009-1 January 21, 2000 1%
City of Greenleaf 136 October 22, 1999 1%
City of Hagerman 1090 May 27, 2021 1%
City of Hailey 1278 August 29, 2019 3%
City of Hazelton 258-2019 April 16, 2019 1%
City of Hollister 04-03-19 June 28, 2019 1%
City of Idaho City 363 September 25, 1996 1%
City of Inkom 21-263 July 26, 1996 1%
City of Jerome 1137 April 1, 2015 1%
City of Ketchum 1246 May 18, 2012 3%
City of Kimberly 622 May 1, 2015 1%
City of Leadore 2018-1 October 2, 2018 1%
City of McCall 862 April 29, 2009 3%
City of Melba 212 February 28, 2007 1%
City of Meridian 800 December 22, 1998 1%
City of Middleton 287 October 22, 1999 1%
City of Mountain Home 1251 October 24, 1996 1%
City of Nampa 3980 October 1, 2012 1.5%
City of New Meadows 306-06 May 30, 2007 3%
City of New Plymouth 331 January 31, 2011 1.5%
City of Notus 259 August 28, 2007 1%
City of Oakley 02-10-22 March 30, 2012 1%
City of Payette 1476 September 29, 2020 1%
City of Pocatello 2956 November 2, 2015 1%
City of Richfield 262 March 27, 1996 3%
City of Rockland 30 April 16, 2019 1%
City of Shoshone 514 June 27, 2008 1%
City of Star 196 August 20, 2009 1%
City of Sun Valley 519 January 26, 2018 1%
City of Twin Falls 2927 March 31, 2008 3%
City of Wendell 529-2016 September 29, 2016 1%
City of Wilder 486 May 27, 2004 1%

Idaho Power Company Original Sheet No. 96-1
Cancels
I.P.U.C. No. 30, Tariff No. 101_ Original Sheet No. 96-1

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 96
BLAINE COUNTY SURCHARGE
TO FUND THE UNDERGROUNDING
OF CERTAIN FACILITIES

PURPOSE

The purpose of this schedule is to set forth the monthly surcharge to fund the incremental cost of
undergrounding certain transmission and distribution facilities at the request of Blaine County. The
monthly surcharge will be billed separately by the Company to its Customers within the corporate limits
of Blaine County.

APPLICABILITY

This schedule is applicable to all Customers served under the Company’s schedules listed below
within the corporate limits of Blaine County.

CHARGE

The applicable monthly surcharge will be applied to Customers’ bills starting on the first bill date
of the month following energization of the facilities and will remain in effect throughout the payback period.
The payback period is assumed to be twenty (20) years. Any over- or under-collection relative to actual
incremental project costs may be addressed through surcharge modification and/or increases or
decreases to the payback period.

Schedule Description Monthly Surcharge
1 Residential Service $3.42
3 Master Metered Mobile Home Park $3.42
5 Residential – Time-of-Day Pilot Plan $3.42
6 Residential Service On-Site Generation $3.42
7 Small General Service $3.42
8 Small General Service On-Site Generation $3.42 
9S Large General Service – Secondary $14.36
9P Large General Service – Primary $14.36
9T Large General Service – Transmission $14.36
19S Large Power Service – Secondary $14.36
19P Large Power Service – Primary $14.36
19T Large Power Service – Transmission $14.36
24 Agricultural Irrigation Service $14.36

Idaho Power Company Original Sheet No. 98-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 98-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT

APPLICABILITY

This schedule is applicable to the Qualifying Electric Energy, as defined below, delivered to
Customers taking service under Schedules 1, 3, 5, 6, 7, 8, 9, 15, or 24.

The Residential and Small Farm Energy Credit (“Credit”) is the result of the Settlement Agreement
between the Company and the Bonneville Power Administration (“BPA”) Contract No. 11PB-12322. The
Settlement Agreement provides for the determination of benefits during the period October 1, 2011,
through September 30, 2028. This schedule shall expire when the benefits derived from the Settlement
Agreement have been credited to Customers as provided for under this schedule.

QUALIFYING ELECTRIC ENERGY

RESIDENTIAL

All kilowatt-hours (kWh) of metered energy, delivered during the Billing Period, to
residential Customers taking service under Schedules 1, 3, 5, or 6 and all kWh of metered
residential electric use delivered to Customers taking service under Schedules 7, 8, 9, or 15, as
defined in the BPA Customer Load Eligibility Guidelines for the Residential Exchange Program
Residential Purchase and Sale Agreements, will be considered Residential Qualifying Electric
Energy under this schedule.

SMALL FARM

All kWh of metered energy, delivered during the Billing Period, to eligible small farm
Customers taking service under Schedule 7, 8, or 9, as defined in the BPA Customer Load
Eligibility Guidelines for the Residential Exchange Program Residential Purchase and Sale
Agreements will be considered Small Farm Qualifying Electric Energy under this schedule.

IRRIGATION

All kWh of metered energy, delivered during the Billing Period, to eligible irrigation
Customers taking service under Schedule 24, as defined in the BPA Customer Load Eligibility
Guidelines for the Residential Exchange Program Residential Purchase and Sale Agreements,
limited to either the irrigation Customer’s actual metered energy or 222,000 kWh, whichever is
less, will be considered Irrigation Qualifying Electric Energy under this schedule. Determination
of Irrigation Qualifying Electric Energy under this schedule will be identified at the Customer level.

Idaho Power Company Original Sheet No. 98-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 98-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT
(Continued)

CREDIT ADJUSTMENT

An energy credit rate will be determined on an annual basis by dividing the sum of the total fiscal
year Credit, derived from the Settlement Agreement, plus a true up from the prior year Credit, if
applicable, by the sum of the calendar year projected Qualifying Electric Energy as described above.
The current energy credit rate is 0.2534 cents per kWh.

For residential and small farm Customers, the adjustment credit will be reflected on Customers’
monthly bills.

For irrigation Customers, the adjustment credit will be issued in December of each year.

Idaho Power Company Original Sheet No. i
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. i
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008January 1, 2024 1221 West Idaho Street, Boise, ID

IDAHO PUBLIC UTILITIES COMMISSION

TARIFF NO. 2930

GENERAL RULES, REGULATIONS AND RATES
APPLICABLE TO ELECTRIC SERVICE IN THE TERRITORY
SERVED FROM THE COMPANY’S INTERCONNECTED SYSTEM
IN IDAHO

Idaho Power Company Fourth RevisedOriginal Sheet No. ii
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Third Fourth Revised Sheet No. ii
IDAHO Issued by IDAHO POWER COMPANY
Issued –Per Order No. February 17, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 21, 2022January 1, 2024 1221 West Idaho Street, Boise, ID
Advice No. 22-01

GENERAL RULES AND REGULATIONS INDEX

SHEET
RULE TITLE NUMBER

Title Page ........................................................................................................................... i
Index Page ................................................................................................................. ii -- iv
Rule A Introduction ................................................................................................................... A-1
Rule B Definitions ............................................................................................................ B-1 -- B-2
Rule C Service and Limitations ....................................................................................... C-1 -- C-2
Rule D Metering ............................................................................................................ D-1 -- D-32
Rule E Master Metering Standards ................................................................................. E-1 -- E-2
Rule F Service Establishment and Discontinuance .................................................................. F-1
Rule G Billings ................................................................................................................ G-1 -- G-2
Rule H New Service Attachments and Distribution Line Installations or Alterations H-1 -- H-14

Rule I Budget Pay Plans ................................................................................................... I-1 -- I-2
Rule J Continuity, Curtailment and Interruption of Electric Service .................................. J-1 – J-4
Rule K Customer’s Load and Operations ........................................................................ K-1 -- K-2
Rule L Deposits ............................................................................................................... L-1 -- L-2
Rule M Facilities Charge Service .................................................................................... M-1 -- M-3

Idaho Power Company Seventh Revised Original Sheet No. iii
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, ID

SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER

1 Residential Service Standard Plan ........................................................................ 1-1 – 1-2
3 Master-Metered Mobile Home Park Residential Service....................................... 3-1 – 3-2
4 Residential Service Energy Watch Pilot Plan (Optional) (Suspended) ................. 4-1 – 4-3
5 Residential Service Time-of-Day PilotUse Plan (Optional) ................................. 5-1 – 5-32
6 Residential Service On-Site Generation ............................................................... 6-1 – 6-6
7 Small General Service .......................................................................................... 7-1 – 7-2
8 Small General Service On-Site Generation .......................................................... 8-1 – 8-5
9 Large General Service ........................................................................................ 9-1 – 9-45
15 Dusk to Dawn Customer Lighting ...................................................................... 15-1 – 15-2
19 Large Power Service ......................................................................................... 19-1 – 19-7
20 Speculative High-Density Load ....................................................................... 20-1 – 20-78
23 Irrigation Peak Rewards Program (Optional) .................................................. 23-1 – 23-10
24 Agricultural Irrigation Service ............................................................................ 24-1 – 24-6
26 Micron Technology, Inc. Special Contract ......................................................... 26-1 – 26-2
29 J.R. Simplot (Pocatello, Idaho) Special Contract ......................................................... 29-1
30 Department of Energy Special Contract ............................................................ 30-1 – 30-2
31 Supply of Standby Electric Service for Amalgamated Sugar Company ....................... 31-1
32 J.R. Simplot (Caldwell, Idaho) Special Contract........................................................... 32-1
33 Brisbie, LLC Special Contract ........................................................................... 33-1 – 33-4

34 Lamb Weston, Inc. ............................................................................................ 34-1 – 34-4
40 Non-Metered General Service .......................................................................... 40-1 – 40-2
41 Street Lighting Service .................................................................................... 41-1 – 41-64
42 Traffic Control Signal Lighting Service ......................................................................... 42-1
45 Standby Service ................................................................................................ 45-1 – 45-5
46 Alternate Distribution Service ............................................................................ 46-1 – 46-4
54 Fixed Cost Adjustment ...................................................................................... 54-1 – 54-2
55 Power Cost Adjustment ..................................................................................... 55-1 – 55-3
60 Solar Photovoltaic Service Pilot Program ......................................................... 60-1 – 60-6
61 Payment for Home Wiring Audit ................................................................................... 61-1
62 Green Energy PurchaseClean Energy Your Way Program Rider (Optional) .. 62-1 – 62-25
63 Community Solar Pilot Program ........................................................................ 63-1 – 63-5
66 Miscellaneous Charges ................................................................................... 66-1 – 66-43
68 Interconnections to Customer Distributed Energy Resources......................... 68-1 – 68-28
72 Generator Interconnections to PURPA Qualifying Facility Sellers .................. 72-1 – 72-28
Idaho Power Company Seventh Revised Original Sheet No. iii
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, ID

73 Cogeneration and Small Power Production Schedule – Idaho ....................... 73-1 – 73-10
79 Weatherization Assistance for Qualified Customers .................................................... 79-1
81 Residential Air Conditioner Cycling Program (Optional) ................................... 81-1 – 81-3
Idaho Power Company Original Sheet No. iii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective –January 1, 2024 1221 West Idaho Street, Boise, ID

SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER

73 Cogeneration and Small Power Production Schedule – Idaho ....................... 73-1 – 73-10
Idaho Power Company Original Sheet No. iii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seventh Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective –January 1, 2024 1221 West Idaho Street, Boise, ID

79 Weatherization Assistance for Qualified Customers .................................................... 79-1
81 Residential Air Conditioner Cycling Program (Optional) ................................... 81-1 – 81-3
Idaho Power Company Original Sheet No. iv
cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. iv
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 15, 2022 1221 West Idaho Street, Boise, ID

82 Flex Peak Program (Optional) ......................................................................... 82-1 – 82-57
84 Customer Energy Production Net Metering Service.......................................... 84-1 – 84-6
86 Cogeneration and Small Power Production Non-Firm Energy .......................... 86-1 – 86-7
87 Intermittent Generation Integration Charges ................................................... 87-1 – 87-24
89 Unit Avoided Energy Cost for Cogeneration and Small Power Production .................. 89-1
91 Energy Efficiency Rider ................................................................................................ 91-1
95 Adjustment for Municipal Franchise Fees ......................................................... 95-1 – 95-2
96 Blaine County Surcharge to Fund the Undergrounding of Certain Facilities ................ 96-1
98 Residential and Small Farm Energy Credit ....................................................... 98-1 – 98-2

Idaho Power Company Original Sheet No. A-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. A-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE A
INTRODUCTION

These Rules and Regulations are a part of the Tariff of Idaho Power Company and apply to the
Company and every Customer to whom service is supplied; provided, that in case of conflict between
these Rules and Regulations and the provisions of any schedule of this Tariff, the provisions of such
schedule will govern as to service supplied thereunder.

Idaho Power Company First RevisedOriginal Sheet No. B-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. B-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per IPUC Order No. 30722 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 1, 2009 1221 West Idaho Street, Boise, Idaho

RULE B
DEFINITIONS

The terms listed below, which are used frequently in this Tariff, will have the stated meanings:

Billing Period is the period intervening between meter readings and shall be approximately 30 days.
However, Electric Service covering 27-36 days inclusive will be considered a normal Billing Period.

Commission refers to the Idaho Public Utilities Commission.

Company refers to Idaho Power Company.

Customer is the individual, partnership, association, organization, public or private corporation,
government or governmental agency receiving or contracting for Electric Service.

Demand is the average kilowatts (kW) or horsepower (HP) supplied to the Customer during the 15-
consecutive-minute period of maximum use during the Billing Period, as shown by the Company's meter,
or determined in accordance with the demand clause in the schedule under which service is supplied. In
no event, however, will the maximum demand for the Billing Period be less than the demand determined
as specified in the schedule.

Electric Service is the availability of power and energy in the form and at the voltage specified in
the Idaho Electric Service Request or agreement, irrespective of whether electric energy is actually
utilized, measured in kilowatt-hours (kWh).

Month (unless calendar month is stated) is the approximate 30-day period coinciding with the Billing
Period.

Normal Business Hours are 8:00 a.m. to 5:00 p.m., Monday through Friday, excluding holidays
observed by the Company. All times are stated in Mountain Time. Notice of office closures for holidays
are posted, in advance, at the Company office entrances.

Point of Delivery is the junction point between the facilities owned by the Company and the facilities
owned by the Customer; OR the Ppoint at which the Company's lines first become adjacent to the
Customer's property; OR as otherwise specified in the Company's Tariff.

Power Factor is the percentage obtained by dividing the maximum demand recorded in kW by the
corresponding kilovolt-ampere (kVA) demand established by the Customer.

Premises is a building, structure, dwelling, suite, or residence of the Customer that is separated by
a demising wall. If the Customer uses several buildings, or structures or suites in the operation of a single
integrated commercial, industrial, or institutional enterprise, the Company may consider all such buildings,
or structures or suites that are in proximity to each other to be the Premises, even though intervening
ownerships or public thoroughfares exist.

Idaho Power Company Original Sheet No. B-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. B-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE B
DEFINITIONS
(Continued)

Service Level is defined as follows:

Secondary Service is service taken at 480 volts or less, or where the definitions of Primary Service
and Transmission Service do not apply. The Company is responsible for providing the transformation of
power to the voltage at which it is to be used by the Customer taking Secondary Service.

Primary Service is service taken at 12.5 kilovolts (kV) to 34.5 kV. Customers taking Primary Service
are responsible for providing the transformation of power to the voltage at which it is to be used by the
Customer.

Transmission Service is service taken at 44 kV or higher. Customers taking Transmission Service
are responsible for providing the transformation of power to the voltage at which it is to be used by the
Customer.

Idaho Power Company Second RevisedOriginal Sheet No. C-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. C-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 15, 2022 1221 West Idaho Street, Boise, Idaho

RULE C
SERVICE AND LIMITATIONS

1. Rates and Tariff. Service supplied by the Company will be in accordance with the Tariff on
file with the state regulatory authority having jurisdiction, and as in effect at the time service is supplied.
All service rates and agreements are subject to the continuing jurisdiction and regulation of such
authority, as provided by law.

When any municipal corporation or other local taxing agency imposes on the Company any
franchise, occupation, sales, license, excise, business, operating, privilege, or use of street tax or
charge based upon meters or Customers, or upon electricity sold or the receipts or income therefrom,
the prorate amount thereof will be billed to all Customers in the area or locality in which such tax or
charge applies and will be separately stated on, and added to, their regular billing.

2. Supplying of Service. Service will be supplied under a given schedule only to Points of
Delivery as are adjacent to facilities of the Company, adequate and suitable as to capacity and voltage for
the service desired and under the schedule applicable thereto. The Company will not be obligated to
construct extensions or install additional service facilities except in accordance with Rule H and to the
Company’s construction standards. In instances where Rule H is not applicable, all other cases, special
agreements between the Customer and the Company may be required.

3. Service Application. The Company will normally accept an application for service from the
Customer by telephone, through the Company’s Wweb site or by other oral communication. The
Company may however, at its discretion, require the Customer to sign an application requesting service.

4. Choice of Schedules. The Company's schedules are designed to provide monthly rates
for service supplied to the Customer on an annual basis. The Customer may elect to take service under
any of the schedules applicable to this annual service requirement, and the Company will endeavor to
assist in the selection of the appropriate schedule most favorable to the Customer. Changing of
schedules will occur only when the characteristics of the Customer's usage change such that another
applicable schedule is deemed more favorable to the Customer when applied to the Customer's annual
service requirements. Customers receiving service under Schedules 7, 8, 9, 19, and 20 will be reviewed
on a monthly basis under the provisions established in the Applicability section of each of these
schedules.

5. Point of Delivery Service Requirements. A Customer may be served at more than one
Point of Delivery at the same Premises if practicable, unless otherwise specified in a schedule. Service at
each Point of Delivery at the same Premises will be offered under the appropriate schedule. The
Customer's request for service at an additional Point of Delivery will be subject to the applicable line
extension rules of the Company. The Company may refuse to provide service at more than one Point of
Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery
cannot be provided without jeopardizing the safety and reliability of the Company's system or service to
the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the
same Premises will not be interconnected electrically.

Idaho Power Company Third RevisedOriginal Sheet No. C-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. C-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– February 14, 2019 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 April 16, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-04

RULE C
SERVICE AND LIMITATIONS
(Continued)

5. Point of Delivery Service Requirements (Continued)

Where separate Points of Delivery exist for supplying service to a Customer at a single
Premises or separate meters are maintained for measurement of service to a Customer at a single
Premises, the meter readings will not be combined or aggregated for any purpose except for
determining if the Customer's total power requirements exceed 20,000 kW. Special contract
arrangements will be required when a Customer's aggregate power requirement exceeds 20,000 kW.

Service delivered at low voltage (600 volts or under) will be supplied from the Company's
distribution system to the outside wall of the Customer's building , or service pole, or post unless an
exception is granted by the Company and the City or State Electrical Inspector.

The Customer's facilities will be installed and maintained in accordance with the requirements of
the National Electrical Code.

6. Limitation of Use. A Customer will not resell electricity received from the Company to any
person except (1) where the Customer is owner, lessee, or operator of a commercial building, shopping
center, apartment house, mobile home court, or other multi-family dwelling where the use has been sub-
metered prior to July 1, 1980, and the use is billed to tenants at the same rates that the Company would
charge for service, unless the Commission authorizes alternative procedures, or (2) where the electricity
is purchased from a public utility (as defined in Idaho Code § 61-129) to charge the batteries of an electric
motor vehicle as provided by order or rule of the Commission.

A Customer's wiring will not be extended or connected to furnish service to more than one
building or place of use through one meter, even though such building, property, or place of use is
owned by the Customer. This rule provision is not applicable where the Customer's residence or
business consists of one or more adjacent buildings or places of use located on the same Premises or
operated as an integral unit, under the same name and carrying on parts of the same residence or
business.

7. Rights of Way. The Customer shall, without cost to the Company, grant the Company a
right of way for the Company's lines and apparatus across and upon the property owned or controlled by
the Customer, necessary or incidental to the supplying of Electric Service and shall permit access thereto
by the Company's employees at all reasonable hours. The Customer shall also grant the Company
access to permit the Company to trim trees and other vegetation to the extent necessary to avoid
interference with the Company’s lines and to protect public safety.

Idaho Power Company First RevisedOriginal Sheet No. D-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. D-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – August 25, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective -– July 1, 2023 – September 25, 2009 1221 West Idaho Street, Boise, Idaho

RULE D
METERING

1. Meter Installations. The Company will install and maintain the metering equipment
required by the Company to measure power and energy supplied to the Customer. Meter installations
will be done at the Company's expense except as specified below or otherwise specified in a schedule.
Customer provisions for meter installations will be made in conformance with Company specifications,
the National Electrical Code, and/or applicable state or municipal requirements.

a. Instrument Transformer Metering. When instrument transformer metering is
requested by the Customer but not required by the Company at the time of the initial meter
installation, the Customer will be required to pay the cost of such metering equipment and its
installation in accordance with the charges specified in Schedule 66. When a Customer requests
instrument transformer metering not required by the Company at a time other than at the time of
the initial meter installation, the actualwork order costs will apply.

b. Off-Site Meter Reading Service. Customers taking single-phase service under
Schedule 1, 4, 5, or 7 may request the Company install metering equipment which provides for off-
site meter reading. The installation fee and monthly charges for off-site meter reading capability,
when the service is requested by the Customer but not deemed to be cost-effective by the
Company, are specified in Schedule 66. The Company shall have the sole right to determine
whether an installation is cost-effective. Customers who request the Company-installed off-site
meter reading equipment be removed within 90 days of initial installation will be assessed a removal
fee in accordance with the provisions of Schedule 66. Due to the specialized nature of the metering
equipment, a delay may occur between the time a Customer requests the Off-Site Meter Reading
Service and the time the equipment is available for installation. Customers utilizing the Off-Site
Meter Reading Service may be required to periodically permit Company personnel access to the
meter in order for maintenance to be performed.

cb. Load Profile Metering. The Company will install, at the Customer’s request, the
metering equipment necessary to provide load profile information. The installation fee and monthly
charges for load profile capability, Wwhen the Load Profile Metering service is requested by the
Customer but not provided by the Company as part of the its standard meter installation, are
specified in Schedule 66 the Customer will pay work order costs for the installation of all equipment
required to provide such service. The options available under the Load Profile Metering Sservice
include: Meter Pulse Output Service, which provides limited kWh and kW load information; Load
Profile Recording Service, which downloads load characteristics and information on a delayed
basis; and Enhanced Metering Information Service, which provides real-time access to load
characteristics and information. Customers requesting the Load Profile Recording Service that the
Company provide Load Profile Metering service are responsible for providing, at their own expense,
a hard-wired or wireless connection phone line to each metering point, and all such connection
equipment will be owned by the Customer unless the configuration of metering equipment
necessitates otherwise. Customers who request the Load Profile Metering Service be discontinued
within 36 months of initial installation will be assessed a removal fee in accordance with the
provisions of Schedule 66.

The Company shall not be liable to any Customer or any other persons for any loss or
damage incurred resulting from the supply or interruption of any Load Profile Metering service. The
Idaho Power Company First RevisedOriginal Sheet No. D-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. D-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – August 25, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective -– July 1, 2023 – September 25, 2009 1221 West Idaho Street, Boise, Idaho
Company does not warrant or guarantee the accuracy, reliability, validity or usability of the
information or data provided by its Load Profile Metering service, and Customers receiving any such
Load Profile Metering service voluntarily assume all responsibility and risk in use of such service’s
information toor data.

c. Primary Voltage Metering. The Company will install, at its own expense, a maximum
of one primary voltage meter at a single Premises to record usage taken at 12.5 kV or 34.5 kV. In
all other circumstances, work order costs will apply.d. Surge Protection Device Services. At
the Customer’s request, the following services are available for watt-hour metered Customers only.

i. Installation or Removal. The Company will install or remove, at the Customer’s
request, a surge protection device supplied by the Customer on the meter base and other utility
peripherals to accommodate whole-house surge protection. A Surge Protection Device Installation
or Removal Charge will be assessed as specified in Schedule 66.

Idaho Power Company Original Sheet No. D-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. D-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE D
METERING
(Continued)

d. Surge Protection Device ServicesMeter Installations (Continued)

The Company will not install any surge protection device without proof that the
vendor of the surge protection device has executed and delivered to the Company an
agreement (in a form acceptable to the Company) which provides for the full defense and
indemnification of the Company by the vendor against any claims, suits, or losses
associated with such device.

Any surge protection device the Company is requested to install on the meter must
be Underwriters’ Laboratories, Inc. certified and meet National Electric Energy Testing,
Research and Application Centers (NEETRAC) test standards or comparable test
standards.

ii. Surge Protection Device Customer Visit Charge.

(1) If a surge protection device installation visit results in the inability of
Company personnel to install the surge protection device due to safety concerns,
inaccessibility to the meter base or other utility access points, or other factors
deemed reasonable by the Company, a Surge Protection Device Customer Visit
Charge will be applied as specified in Schedule 66. The Company has the sole
right to ultimately determine installation feasibility.

(2) Customers who request the Company perform an on-site visit to
assess alleged electrical problems believed to be associated with the surge
protection product will be charged a Surge Protection Device Customer Visit
Charge as specified in Schedule 66 if no problems associated with the electrical
service are found as a result of the visit.

ec. Primary Voltage Metering. The Company will install, at its own expense, a maximum
of one primary voltage meter at a single Premises to record usage taken at 12.5 kV or 34.5 kV. In
all other circumstances, work order costs will apply.

2. Measurement of Energy. Except as otherwise specifically provided, all energy delivered by
the Company will be billed according to measurement by meters located at or near the Point of Delivery.

If the Company is unable to read obtain a Customer's meter reading(s)because of reasons beyond
the Company's control, such as weather conditions or the inability to obtain access to the Customer's
Premises, the Company may estimate the meter reading(s) for the Billing Period on the basis of the
Customer's previous use, season of the year and use by similar Customers of the same class in that
service area. Bills rendered based on an estimated monthly read,ings or when a Billing Period includes
more than twenty-four unscaled hourly reads, will be so designated as estimated on the bill. The amount
of such estimated bill will be subsequently adjusted, as necessary, when practicable, when the next
actual reading is obtained.
Idaho Power Company Original Sheet No. D-22
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. D-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE D
METERING
(Continued)

3. Failure to Register. If the Company's meters fail to register at any time, the service delivered
and energy consumed during such period of failure will be determined by the Company on the basis of the
best available data. If any appliance or wiring connection, or any other device, is found on the Customer's
Premises which prevents the meters from accurately recording the total amount of energy used on the
Premises, the Company may at once remove any such wiring connection or appliance, or device, at the
Customer's expense, and will estimate the amount of energy so consumed and not registered as accurately
as it is able so to do, and the Customer will pay for any such energy within 5 days after being billed, in
accordance with such estimate.

4. Meter Tests. The Company will test and inspect its meters from time to time and maintain
their accuracy of registration in accordance with generally accepted practices and the rules and regulations
established by the Idaho Public Utilities Commission. The Company will, without charge, test the accuracy
of registration of a meter upon request of a Customer, provided that the Customer does not request such
a test more frequently than once in a 12-month period. If more than one requested test is performed within
a 12-month period, the Customer will be required to pay in advance the cost of a special meter test as
specified in Schedule 66. The Company will refund the amount paid by the Customer for the test if the
results of the test show the average registration error of the meter exceeds ±2 percent.

5. Transformer Losses. When delivery of service is on the primary side of the Customer's
transformers, the Company may install its meters on the secondary side of the transformers, and, unless
otherwise provided in the schedule, in determining the monthly consumption of power and energy,
transformer losses and other losses occurring between the Point of Delivery and the meters will be
computed and added to the reading of such meters.

6. Meter Reading. Meters will be read to the last kWh registered, normally at intervals of
approximately 30 days for monthly register reads and daily for hourly interval reads. In no case will the
meter reading interval exceed 45 days.
Idaho Power Company Original Sheet No. D-32
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. D-32
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE D
METERING
(Continued)

[Intentionally Left Blank]

Idaho Power Company First RevisedOriginal Sheet No. E-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. E-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30754 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 April 10, 2009 1221 West Idaho Street, Boise, Idaho

RULE E
MASTER METERING STANDARDS

1. Definitions:

a. Tenant--Mobile Home Park. A tenant of a mobile home park is a person defined as
a tenant resident and not a transient by the Mobile Manufactured Home Park Tenant Residency
Act, sSection 55-2001 et seq., Idaho Code, and in particular by Section 55-2003(164) and -(55-
2003(19), Idaho Code.

b. Tenant--Multi-Unit Residential or Commercial Building. A tenant of a multi-unit
residential building is a person who is not a transient and who intends to reside in or be a commercial
tenant in one of the building's units for a period of not less than one month.

2. Master-Metering and Individual Metering in Mobile Home Parks:

a. Parks metered after July 1, 1980. Tenants (excluding transients) of mobile home
parks connected for service after July 1, 1980, must be individually metered by the Company.
Master-metering of these tenants, whether or not in conjunction with sub-metering by the park
operator, is prohibited.Master Metering Prohibited. Master-metering, whether or not in conjunction
with sub-metering of electric service by the park operator, is prohibited for any mobile home park
connected for service by the Company after July 1, 1980. After that date, tenants (excluding
transients) of mobile home parks must be individually metered and billed by the Company.

b. Exception for Grandfathered Sub-Metered Parks. Any Mmobile home parks
connected for service on or before July 1, 1980, whose spaces for non-transient tenants (excluding
transients) have been fully sub-metered for electricity by the park owners need not be individually
metered by the Company. A Mmobile home parks sub-metered by the park operator must charge
each of their tenants the same rate for electric service that a Customer of the Company would be
charged if the tenant were directly metered and billed by the Company under Schedule 3 – Master-
Metered Mobile Home Park – Residential Service. Testing of sub-meters will be at the park
operator's expense.

c. Parks metered prior to July 1, 1980. Transition Rule for Sub-Metered Parks. Mobile
home parks that were partially sub-metered on July 1, 1980, must have individually metered all spaces to
be used by non-transient tenants before January 1, 1981. At the option of the park operator, the operator
may extend an existing sub-metering system to those spaces not metered by the operator or may request
the Company to meter the unmetered spaces for non-transient tenants at the Company's expense.
3. Master-Metering and Individual Metering in Multi-Occupant Residential Buildings. Non-
transient tenants of multi-occupant residential buildings connectedwill be master-metered for
electric service after July 1, 1980, will be individually metered and billed by the Company if the
dwelling units for nontransient such tenants contain an electric space heating, water heating, or air-
conditioning (space cooling) unit that is not centrally controlled and for which the dwelling unit'ssaid
tenants individually control electric usage.

4. Master-Metering and Individual Metering in Commercial Buildings and Shopping Centers.
No unit of cCommercial buildings and shopping centers will be master-meteredconnected for
electric service after July 1, 1980, may not be master-metered if the units for non-transient their
tenants contain an electric space heating, water heating, or air-conditioning (space cooling) unit that
is not centrally controlled and over for which the unit's tenants individually control electric usage.
Idaho Power Company First RevisedOriginal Sheet No. E-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. E-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30754 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 April 10, 2009 1221 West Idaho Street, Boise, Idaho
Any non-transient Ttenants in otherwise master-metered buildings will be individually metered and
billed by the Company if the tenant’s whoseelectric load is significantly greater than that of the other
tenants in the building or shopping center, or exceeds the individual metering threshold found in the
Company's Tariff must be individually metered.

d. Company Payment for Reading Sub-Meters. The Company will pay the park
operator $1.15 per month per sub-metered occupied customer space. The Company will only pay
$1.15 per month per space that is occupied during the month.

e. List of Grandfathered Mobile Home Parks. The Company will file with the
Commission a list of "grandfathered" mobile home park operators who are entitled to a payment for
sub-metered occupied customer spaces. Each month, the owner-operator will certify to the
Company the number of spaces that were occupied during the month. The Company will have the
right to request from the owner-operator reasonable documentation of any customer account be
provided to the Company.

Idaho Power Company Original Sheet No. E-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. E-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE E
MASTER METERING STANDARDS
(Continued)

[Intentionally Left Blank]
Idaho Power Company First Revised Original Sheet No. F-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. F-1
IDAHO Issued by IDAHO POWER COMPANY
Issued June 24, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective August 1, 2015 – January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 15-07

RULE F
SERVICE ESTABLISHMENT AND
DISCONTINUANCE

1. Service Establishment. A Service Establishment Charge as specified in Schedule 66,
unless otherwise specified in a different schedule, will be assessed upon initiating metered service with
the Company if service at the Point of Delivery is currently energized. The applicable charge will be
billed with the first regular bill.

a. Owners or managers of rental property that arrange with the Company to provide
continuous service between tenants will not be assessed a Service Establishment Charge when
the service reverts to the responsible party as arranged.

2. Continuous Service. At the request of owners or managers of rental property, the
Company will provide continuous service between tenant occupancy. Effective August 1, 2006 a A
Continuous Service Reversion Charge, as specified in Schedule 66, will be assessed each time the
service reverts to the responsible party as arranged.

3. Service Connection. Where service at the specified Point of Delivery is currently
disconnected from the Company’s system, a Service Connection Charge or Remote Service
Connection Charge, as specified in Schedule 66, will be assessed at the time service is connected.
The applicable charge will be billed with the first regular bill. The Service Connection Charge applies
to all service connections, except for remote service connections, for both metered and unmetered
service. The Remote Service Connection Charge applies only to those service connections where
remote capability of reconnection is available and when service is connected remotely. The Service
Establishment Charge does not apply when service is reconnected.

4. Service Discontinuance. At the Customer’s request, the Company will disconnect
service during normal working hours. There is no charge for discontinuing service.

a. When a Customer requests service be discontinued, service will not be
disconnected if another party has agreed to accept responsibility for service at the Point of
Delivery. Upon initiating service, the Customer requesting service will be billed a Service
Establishment Charge in accordance with this rule.

5. Termination Practices. The Company's practices relating to Termination of Service are
governed by the Utility Customer Relations Rules (UCRRs) of the Idaho Public Utilities Commission, in
effect at the time the event occurred which required application of the UCRRs. If the Company's Rules
and Regulations on file with the Idaho Public Utilities Commission contain provisions which conflict with
the UCRRs, the provisions of the respective UCRRs supersede those included in the Company's Rules
and Regulations.

6. Field Visit. A Field Visit Charge, as specified in Schedule 66, will be assessed when a
Company representative visits a service address intending to disconnect or connect service, but due to
Customer action, the Company representative is unable to complete the disconnection or connection at
the time of the visit. Examples of Customer action include, but are not limited to, a) the Customer
making a payment at the door, or b) obstructing the Company’s access to the Customer’s meter or
threatening to cause or causing physical harm to the Company representative.

Idaho Power Company Third RevisedOriginal Sheet No. G-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. G-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 15, 2022 1221 West Idaho Street, Boise, Idaho

RULE G
BILLINGS

1. Fractional Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the Energy Charge for service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, 20, or 24 will be
calculated using actual meter readings. The Energy Charge for service provided under Schedule 40 will
be determined using the daily kWh calculated on the basis of load size and number of units served
multiplied by the actual number of days since the account was opened or since the previous billing, where
appropriate. The proration of the applicable Demand Charge, Basic Charge, Facilities Charge, and
Service Charge specified in the appropriate schedule will be calculated by dividing the charge by 30 and
multiplying the result by the actual number of days since the account was opened or since the previous
meter reading, where appropriate. However, the prorated Service Charge for Schedules 1, 3, 4, 5, 6, 7,
8, 9, 19, 20, or 24 or the Minimum Charge for Schedule 40, will be no less than the amount specified in
Schedule 66. For Schedule 15, the proration of the applicable Monthly Charge will be calculated by
dividing the charge by 30 and multiplying the result by the actual number of days since the account was
opened or the previous billing, where appropriate; however, in no event will the charge be less than the
Fractional Period Minimum Billings amount specified in Schedule 66.

2. Corrected Billings. Whenever it is determined that a Customer was billed under an
inappropriate schedule, the Customer will be rebilled under the appropriate schedule; however, except if
the Company selected the schedule on the basis of available information and acted in good faith, the
Company will not be required to rebill or adjust billings. When the customer has been overcharged, the
rebilling period will be no more than the 3-year period as provided by Idaho Code § 61-642. When the
customer has been undercharged, the rebilling period shall be limited to six months unless a reasonable
person should have known of the inappropriate billing, in which case the rebilling period may be extended
for a period not to exceed three years, except for counties in which case the rebilling period may not exceed
one year as provided by Idaho Code § 31-1501.

If the average error for any meter test exceeds ±2 percent, corrected billings will be
prepared. The corrected billings will not exceed 6 months if the time when the malfunction or error began
is unknown. If the time when the malfunction or error began is known and the customer was overcharged,
the corrected billings will be from that time, but will not exceed the 3- year period as provided by Idaho
Code § 61-642. If the time when the malfunction or error began is known and the customer was
undercharged, the Company will rebill for a period of six months unless a reasonable person should have
known of the inaccurate billing, in which case the rebilling may be extended for a period not to exceed three
years. If an under-billing occurs, the Company will offer and enter into reasonable payment arrangements
with the Customer. For any over-billings, the Customer will have the choice of a refund or a credit on future
bills.

3. Due Dates. The Company's practices relating to Due Dates are governed by the Utility
Customer Relations Rules (UCRRs) of the Idaho Public Utilities Commission, in effect at the time the
event occurred which required application of the UCRRs. If the Company's Rules and Regulations on
file with the Idaho Public Utilities Commission contain provisions which conflict with the UCRRs, the
provisions of the respective UCRRs supersede those included in the Company's Rules and Regulations.

4. Returned Checks. Checks or payments remitted by Customers in payment of bills are
accepted conditionally. A Returned Check Charge, as specified in Schedule 66, will be assessed to the
Customer for handling each check or payment upon which payment has been refused by the bank.

Idaho Power Company Second RevisedOriginal Sheet No. G-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. G-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – March 16, 2020 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 16, 2020 1221 West Idaho Street, Boise, Idaho
Advice No. 20-01

RULE G
BILLINGS
(Continued)

5. Late Payments. A Late Payment Charge, as provided in Schedule 66, may be levied
against any delinquent account except for accounts of agencies and taxing districts of the State of Idaho
as described in paragraph 6 of this schedule. All payments received by the billing date will apply to the
Customer's account prior to calculating the Late Payment Charge. Payments will satisfy the oldest portion
of the billing first and the current portion of the billing last.

Late Payment Charges will continue to accrue against unpaid disputed bill amounts. If the
dispute is resolved in favor of the Customer, all disputed charges plus any associated Late Payment
Charges will be deleted from the Customer’s account. If the dispute is resolved in favor of the Company,
all disputed charges plus any associated Late Payment Charges will become due and payable.

6. Late Payments for Agencies and Taxing Districts of the State of Idaho. Under the authority
of Idaho Code § 67-2302, an agency or taxing district, as defined within Idaho Code § 63-3101, of the
State of Idaho has 60 days from the date that the bill is received to pay that bill. If a state agency or taxing
district does not pay the bill within the 60-day period, all of the provisions of Idaho Code § 67-2302 will
apply and the Late Payment Charge as specified in Schedule 66 will be levied against the delinquent
account.

Any state agency or taxing district that claims that it falls within the provisions of Idaho Code
§ 67-2302 must notify Idaho Powerthe Company in writing of such claim.

7. Temporary Suspension of Demand. When the Customer is obliged temporarily to
suspend operation due to strikes, actions of any governmental authority, acts of God or the public enemy,
the Customer may procure a proration of the monthly Billing Demand based upon the period of such
suspension by giving immediate written notice to the Company. However, all monthly Minimum Charges
and/or obligations will continue to apply as specified in the applicable schedule or a written agreement.

Idaho Power Company Third Revised Original Sheet No. H-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. H-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 15, 2022 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS

This rule applies to requests for electric service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, 20, 24,
45, and 46 that require the installation, alteration, relocation, removal, or attachment of Company-owned
distribution facilities. New construction beyond the Point of Delivery for Schedule 9 or Schedule 19 is
subject to the provisions for facilities charges under those schedules. This rule does not apply to
transmission or substation facilities, or to requests for electric service that are of a speculative nature.

1. Definitions

Additional Applicant is a person or entity whose Application requires the Company to provide new
or relocated service from an existing section of distribution facilities with a Vested Interest.

Allowance is the portion of a Work Order Cost’s Terminal Facilities funded by the Company.

Alteration is any change or proposed change to existing distribution facilities. An alteration may
include Relocation, Upgrade, Conversion, and/or removal.

Applicant is a person or entity whose Application requires the Company to provide new or
relocated service from distribution facilities that are free and clear of any Vested Interest.

Application is a request by an Applicant or Additional Applicant for new electric service from the
Company. The Company, at its discretion, may require the Applicant or Additional Applicant to
sign a written application.

Company Betterment is that portion of the Work Order Cost of a Line Installation and/or Alteration
that provides a benefit to the Company not required by the Applicant or Additional Applicant.
Increases in conductor size and work necessitated by the increase in conductor size are
considered a Company Betterment if the Connected Load added by the Applicant or Additional
Applicant is less than 100 kilowatts. If, however, in the Company’s discretion, it is determined
that the additional Connected Load added by the Applicant or Additional Applicant, even though
less than 100 kilowatts, is (1) located in a remote location, or (2) a part of a development or project
which will add a load greater than 100 kilowatts, the Company will not consider the work
necessitated by the load increase to be a Company Betterment.

Connected Load is the total nameplate kW rating of the electric loads connected for commercial,
industrial, or irrigation service. Connected Load for residences is considered to be 25 kW for
residences with electric space heat and 15 kW for all other residences.

Conversion is a request by a customer to replace overhead facilities with underground facilities.

Cost Quote is a written cost estimate provided by the Company that must be signed and paid by
the Applicant or Additional Applicant prior to the start of construction. Cost Quotes are derived
from Work Order Cost estimates.

Easement is the Company’s legal right to use the real property of another for the purpose of
installing or locating electric facilities.
Idaho Power Company Third Revised Original Sheet No. H-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. H-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 15, 2022 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original Sheet No. H-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. H-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– November 27, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 December 1, 2009 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Fire Protection Facilities are water pumps and other fire protection equipment, served separately
from the Applicant's other electric load, which operate only for short periods of time in emergency
situations and/or from time to time for testing purposes.

Line Installation is any installation of new distribution facilities owned by the Company. Line
Installations are exclusive of Service Attachments and Terminal Facilities and andare eligible for
Vested Interest Refunds.

Line Installation Allowance is the portion of the estimated cost of a Line Installation funded by the
Company.

Line Installation Charge is the partially refundable charge assessed to an Applicant or Additional
Applicant whenever a Line Installation is built for that individual.

Local Improvement District is an entity created by an authorized governing body under the
statutory procedures set forth in Idaho code, Title 50, Chapter 17 or Idaho Code § 40-1322. For
the purpose of Rule H, the term LID also includes Urban Redevelopment projects set forth in
Idaho Code, Title 50, Chapter 20.

Multiple Occupancy Projects are projects that are intended to be occupied by more than four
owners or tenants. Examples include, but are not limited to, condominiums and apartments.

Point of Delivery is the junction point between the facilities owned by the Company and the
facilities owned by the customer; OR the point at which the Company’s lines first become adjacent
to the customer’s property; OR as otherwise specified in the Company’s tariff.

Prior Right of Occupancy is a designated area within the public road right-of-way where the
Company and the Public Road Agency have agreed that the costs of the Relocation of facilities
in the designated area will be borne by the Public Road Agency. For example, a Prior Right of
Occupancy may be created when the Public Road Agency expands the public road right-of-way
to encompass a Company Easement without compensating the Company for acquiring the
Easement but the parties agree in writing that the subsequent Relocation of distribution facilities
within the designated area will be borne by the Public Road Agency.

Private Beneficiary is any individual, firm or entity that provides funding for road improvements
performed by a Public Road Agency or compensates the Company for the Relocation of
distribution facilities as set forth in Section 10. A Private Beneficiary may include, but is not
limited to, real estate developers, adjacent landowners, or existing customers Customers of the
Company.

Idaho Power Company Original Sheet No. H-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. H-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– November 27, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 December 1, 2009 1221 West Idaho Street, Boise, Idaho
Public Road Agency is any state or local agency which constructs, operates, maintains or
administers public road rights-of-way in Idaho, including where appropriate the Idaho
Transportation Department, any city or county street department, or a highway district.
Idaho Power Company First RevisedOriginal Sheet No. H-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. H-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32473 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2012 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Relocation is a change in the location of existing distribution facilities.

Residence is a structure built primarily for permanent domestic dwelling. Dwellings where
tenancy is typically less than 30 days in length, such as hotels, motels, camps, lodges, clubs, and
structures built for storage or parking do not qualify as a Residence.

Service Attachment is the interconnection between the Company’s distribution system and the
Applicant’s or Additional Applicant’s Point of Delivery.

Shared Terminal Facilities is when two or more existing Residential, General Service, or Irrigation
Customers receive service from any portion of the same Terminal Facilities.

Standard Terminal Facilities are the overhead Terminal Facilities the Company considers to be
most commonly installed for overhead single phase and three phase services. Single phase
Standard Terminal Facilities include the cost of providing and installing one overhead #2
aluminum service conductor service conductor and one 25 kVA transformer to serve a 200
amperage meter base. Three phase Standard Terminal Facilities include the cost of providing
and installing one overhead #2 aluminum service conductor service conductor and three 15 kVA
transformers to serve a 200 amperage meter base.

Subdivision is the division of a lot, tract, or parcel of land into two or more parts for the purpose
of transferring ownership or for the construction of improvements thereon that is lawfully
recognized, platted and approved by the appropriate governmental authorities.

Temporary Line Installation is a Line Installation for electric service of 18 calendar months or less
in duration.

Temporary Service Attachment is a Service Attachment to a customer-provided temporary meter
pole or post which typically furnishes electric service for construction for 18 calendar months or
less in duration.

Terminal Facilities include the transformer, andmeter, overhead service conductor, or
underground conduit (where applicable). These facilities are not eligible for Vested Interest
Refunds.

Underground Service Attachment Charge is the non-refundable charge assessed to an Applicant
or Additional Applicant whenever new underground service is required by a customer attaching
to the Company's distribution system.

Idaho Power Company Twelfth RevisedOriginal Sheet No. H-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Eleventh Twelfth Revised Sheet No. H-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

1. Definitions (Continued)

Unusual Conditions are construction conditions not normally encountered, but which the
Company may encounter during construction which impose additional, project-specific costs.
These conditions may include, but are not limited to: frost, landscape replacement, road
compaction, pavement replacement, chip-sealing, rock digging/trenching, boring, nonstandard
facilities or construction practices, and other than available voltage requirements.

Costs associated with unusual conditions are separately stated and are subject to refund if not
encountered. If unusual conditions are not encountered, the Company will issue the appropriate
refund within 930 days of completion of the project’s reconciliation of costs.

Upgrade is a request by a customer to increase capacity and/or size of Company-owned
distribution facilities. Upgrades are eligible for Vested Interest Refunds.

Vested Interest is the right to a refund that an Applicant or Additional Applicant holds in a specific
section of distribution facilities when Additional Applicants attach to that section of distribution
facilities.

Vested Interest Charge is an amount collected from an Additional Applicant for refund to a Vested
Interest Holder.

Vested Interest Holder is an entity that has paid a refundable Line Installation Charge to the
Company for a Line Installation. A Vested Interest Holder may also be an entity that has paid a
refundable charge to the Company under the provisions of a prior rule or schedule.

Vested Interest Refund is a refund payment to an existing Vested Interest Holder resulting from
a Vested Interest Charge to an Additional Applicant.

Vested Interest Portion is that part of the Company’s distribution system in which a Vested Interest
is held.

Work Order Cost is a cost estimate performed by the Company for a specific request for service
by an Applicant or Additional Applicant. The Work Order Cost will include general overheads of
10.64 percent.

Idaho Power Company First Revised Original Sheet No. H-5
Cancels
I.P.U.C. No. 30 29, Tariff No. 101Original First Revised Sheet No. H-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32473 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2012 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
2. General Provisions

a. Cost Information. The Company will provide preliminary cost information addressing in
the charges contained in this rule, to potential Applicants and/or Additional Applicants.
This preliminary information will not be considered a formal Cost Quote and will not be
binding on the Company or Applicant but rather will assist the Applicant or Additional
Applicant in the decision to request a formal Cost Quote. Upon receiving a request for a
formal Cost Quote, the Applicant or Additional Applicant will be required to provide all
necessary information for a design and prepay non-refundable engineering costs to the
Company. A Cost Quote will be binding in accordance with its terms.

b. Ownership. The Company will own all distribution line facilities and retain all rights to
them.

c. Rights-of-Way and Easements. The Company will construct, own, operate, and maintain
lines only along public streets, roads, and highways that the Company has the legal right
to occupy, and on public lands and private property across which rights-of-way or
easements satisfactory to the Company will be obtained at the Applicant’s or Additional
Applicant’s expense.

d. Removals. The Company reserves the right to remove any distribution facilities that have
not been used for 1-year. Facilities shall be removed only after providing 60 days’ written
notice to the last customer of record and the owner of the property served.

e. Property Specifications. Applicants or Additional Applicants must provide the Company
with final property specifications as required and approved by the appropriate
governmental authorities. These specifications may include but are not limited to:
recorded plat maps, utility easements, final construction grades, property pins and proof
of ownership.

f. Undeveloped Subdivisions. When electric service is not provided to the individual spaces
or lots within a Subdivision, the Subdivision will be classified as undeveloped.

g. Mobile Home Courts. Owners of mobile home courts with transient tenants, as defined
within Idaho Code § 55-2003(19), will install, own, operate, and maintain all termination
poles, pedestals, meter loops, and conductors from the Point of Delivery.

h. Conditions for Start of Construction. Construction of Line Installations and Alterations will
not be scheduled until the Applicant or Additional Applicant pays the appropriate charges
to the Company.

i. Terms of Payment. All payments listed under this section will be paid to the Company in
cash, a minimum of 30 days and no more than 120 days, prior to the start of Company
construction, unless mutually agreed otherwise.
Idaho Power Company First RevisedOriginal Sheet No. H-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. H-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32473 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2012 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

2. General Provisions (Continued)

j. Interest on Payment. If the Company does not start construction on a Line Installation or
Alteration within 30 days after receipt of the construction payment, the Company will
compute interest on the payment amount beginning on the 31st day and ending once
Company construction actually begins. Interest will be computed at the rate applicable
under the Company's Rule L. If this computation results in a value of $10.00 or more, the
Company will pay such interest to the Applicant, Additional Applicant, or subdivider. An
Applicant, Additional Applicant, or subdivider may request to delay the start of construction
beyond 30 days after receipt of payment in which case the Company will not compute or
pay interest.

k. Fire Protection Facilities. The Company will provide service to Fire Protection Facilities
when the Applicant pays the f ull costs of Work Order Cost for the Line Installation
including Terminal Facilities, less Company Betterment. These costs are not subject to
an Line Installation Allowance, but are eligible for Vested Interest Refunds under Section
8.a.

l. Customer Provided Trench Digging and Backfill. The Company will, at its discretion, allow
an Applicant, Additional Applicant or subdivider to provide trench digging and backfill. In
a joint trench, backfill must be provided by the Company. Costs of customer-provided
trench and backfill will be removed from or not included in the Cost Quote and will not be
subject to refund.

3. Line Installation Charges

If a Line Installation is required, the Applicant or Additional Applicant will pay a partially refundable
Line Installation Charge equal to the Work Order Cost less applicable Line Installation Allowances
identified in Section 7.

Idaho Power Company Fifteenth RevisedOriginal Sheet No. H-7
Cancels
I.P.U.C. No. 30 29, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. H-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

4. Service Attachment Charges

a. Overhead Service Attachment Charge. If an overhead Service Attachment is required,
the Applicant or Additional Applicant will pay a non-refundable Service Attachment Charge
equal to the Work Order Cost less applicable Service Attachment aAllowances identified
in Section 7.

b. Underground Service Attachment Charge. Each Applicant or Additional Applicant will pay
a non-refundable Underground Service Attachment Charge for attaching new Terminal
Facilities to the Company's distribution system. The Company will determine the location
and maximum length of service cable.

i. Single Phase 400 Amps or Less and Single Phase Self-Contained Multiple Meter
Bases 500 Amps or Less.

Underground Service Cable (Base charge plus Distance charge)
Base charge from:
underground $ 26.00
overhead including 2" riser $ 965.00
overhead including 3" riser $1,185.00

Distance charge (per foot)
Company Installed Facilities with:
1/0 underground cable $ 14.23
4/0 underground cable $ 14.85
350 underground cable $ 19.30

Customer Provided Trench & Conduit with:
1/0 underground cable $ 3.67
4/0 underground cable $ 4.29
350 underground cable $ 6.16

ii. All Three Phase, Single Phase Greater than 400 Amps, and Single Phase Self-
Contained Multiple Meter Bases Greater Than 500 Amps.

If a three phase, single phase greater than 400 amp, or single phase self-contained
multiple meter base greater than 500 amp underground Service Attachment is
required, the Applicant or Additional Applicant will pay a non-refundable
Underground Service Attachment Charge equal to the Work Order Cost.

Idaho Power Company Fourteenth RevisedOriginal Sheet No. H-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101Thirteenth Fourteenth Revised Sheet No. H-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

5. Vested Interest Charges

Additional Applicants connecting to a vested portion of a Line Installation will pay a Vested Interest
Charge to be refunded to the Vested Interest Holder. Additional applicants will have two payment
options:

Option One - An Additional Applicant may choose to pay an amount determined by this
equation:

Vested Interest Charge = A x B x C where;

A = Load Ratio: Additional Applicant’s Connected Load divided by the sum of
Additional Applicant’s Connected Load and Vested Interest Holder's load.
B = Distance Ratio: Additional Applicant’s distance divided by original distance.
C = Vested Interest Holder’s unrefunded contribution.

Option Two - An Additional Applicant may choose to pay the current Vested Interest, in
which case the Additional Applicant will become the Vested Interest Holder and, as such,
will become eligible to receive Vested Interest Refunds in accordance with Section 8.a.

If Option One is selected, the Additional Applicant has no Vested Interest and the previous Vested
Interest Holder remains the Vested Interest Holder. The Vested Interest Holder's Vested Interest
will be reduced by the newest Additional Applicant's payment.
The Vested Interest Charge will not exceed the sum of the Vested Interests in the Line Installation.
If an Additional Applicant connects to a portion of a vested Line Installation which was established
under a prior rule or schedule, the Vested Interest Charges of the previous rule or schedule apply
to the Additional Applicant.

6. Other Charges

a. Alteration Charges. If an Applicant or Additional Applicant requests a Relocation,
Upgrade, Conversion or removal of Company facilities, the Applicant or Additional
Applicant will pay a non-refundable charge equal to the Cost Quote.

b. Engineering Charge. Applicants or Additional Applicants will be required to prepay all
engineering costs for Line Installations and/or Alterations greater than 16 estimated hours.
Estimates equal to or less than 16 hours will be billed to the Applicant or Additional
Applicant as part of the construction costs, or after the engineering is completed in
instances where construction is not requested. Engineering charges will be calculated at
$87.00 per hour.

Idaho Power Company Twelfth RevisedOriginal Sheet No. H-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101Eleventh Twelfth Revised Sheet No. H-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

c. Engineering Charges for Agencies and Taxing Districts of the State of Idaho. Under the
authority of Idaho Code Section § §67-2302, an agency or taxing district of the State of
Idaho may invoke its right to decline to pay engineering charges until the engineering
services have been performed and billed to the agency or taxing district. Any state agency
or taxing district that claims it falls within the provisions of Idaho Code § 67-2302 must
notify Idaho Power of such claim at the time Idaho Power requests prepayment of the
engineering charges. Idaho Power may require that the state agency or taxing district’s
claim be in writing. If the state agency or taxing district that has invoked the provisions of
Idaho Code Section § §67-2302 does not pay the engineering charges within the 60- day
period as provided in that statute, all the provisions of that statute will apply.

d. Joint Trench Charge. Applicants, Additional Applicants, and subdividers will pay the
Company for trench and backfill costs included in the Cost Quote. In the event the
Company is able to defray any of the trench and backfill costs by sharing a trench with
other utilities, the cost reduction will be included in the Cost Quote.

e. Rights-of-Way and Easement Charge. Applicants or Additional Applicants will be
responsible for any costs associated with the acquisition of rights-of-way or easements.

f. Temporary Line Installation Charge. Applicants or Additional Applicants will pay the
installation and removal costs of providing Temporary Line Installations.

g. Temporary Service Attachment Charge. Applicants or Additional Applicants will pay for
Temporary Service Attachments as follows:

i. Underground - $69.00

The Ccustomer-provided meter post pole must be set within two linear feet of the
Company's existing transformer or junction box.

Idaho Power Company Twelfth RevisedOriginal Sheet No. H-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101Eleventh Twelfth Revised Sheet No. H-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

g. Temporary Service Attachment Charge (Continued)

ii. Overhead - $379.00

The Ccustomer-provided meter pole shall be set in a location that does not require
more than 100 feet of #2 aluminum service conductor that can be readily attached
to the permanent location by merely relocating it.

The electrical facilities provided by the Ccustomer on the meter pole shall be
properly grounded, electrically safe, meet all clearance requirements, and ready
for connection to Company facilities.

The Ccustomer shall obtain all permits required by the applicable state, county, or municipal
governments and will provide copies or verification to the Company as required. The above
conditions must be satisfied before the service will be attached.

h. Temporary Service (Overhead or Underground), Overhead Permanent, and Customer
Provided Trench Inspection Return Trip Charge. A Return Trip Charge of $69.00 will be
assessed each time Company personnel are dispatched to the job site, but are unable to
connect the service. The charge will be billed after the conditions have been satisfied
and the connection has been made.

i. Unusual Conditions Charge. Applicants, Additional Applicants, and subdividers will pay
the Company the additional costs associated with any Unusual Conditions included in the
Cost Quote. This payment, or portion thereof, will be refunded to the extent that the
Unusual Conditions are not encountered.

In the event that the estimate of the Unusual Conditions included in the Cost Quote is equal to or greater
than $10,000, the Applicant, Additional Applicant or subdivider may either pay for the Unusual Conditions
or, at the option of the Company, may furnish an Irrevocable Letter of Credit drawn on a local bank or
local branch office issued in the name of Idaho Power Company for the amount of the Unusual
Conditions. Upon completion of that portion of the project which included an Unusual Conditions
estimate, Idaho Power Company will bill the Applicant, Additional Applicant or subdivider for the amount
of Unusual Conditions encountered up to the amount established in the Irrevocable Letter of Credit. The
Applicant, Additional Applicant or subdivider will have 15 days from the issuance of the Unusual
Conditions billing to make payment. If the Applicant, Additional Applicant or subdivider fails to pay the
Unusual Conditions bill within 15 days, Idaho Power will request payment from the bank.
Idaho Power Company Fifteenth RevisedOriginal Sheet No. H-11
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. H-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 15, 2023 1221 West Idaho Street, Boise, Idaho
Advice No. 22-04

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

j. Underground Service Return Trip Charge. When a residential Ccustomer agrees to
supply the trench, backfill, conduit, and compaction for an underground service, an
Underground Service Return Trip Charge of $114.00 will be assessed each time the
Company’s installation crew is dispatched to the job site at the Ccustomer’s request, but
is unable to complete the cable installation and energize the service due to the Company’s
required specifications not being met.

7. Line Installation, Shared Terminal Facilities and Service Attachment Allowances

The Company will contribute an aAllowance toward the cost of Terminal Facilities and Line
Installation costs necessary for associated with an additional Line Installations and/or Service
Attachments. If a Customer increases their consumptive load and is responsible for upgrading
Shared Terminal Facilities, such Customer will receive an Allowance toward the cost of the
upgraded Shared Terminal Facilities. Allowances are based on the cost of providing and installing
Standard Terminal Facilities for single phase and three phase services.

a. Allowances for Overhead and Underground Line Installations, Shared Terminal Facilities
and Overhead Service Attachments

Class of Service Maximum Allowance per Service

Residential:
Schedules 1, 3, 4, 5, 6 $3,360.00
Non-residence $ 0.00

Non-residential:
Schedules 7, 8, 9, 24
Single Phase $3,360.00
Three Phase $6,890.00

Large Power Service
Schedule 19 Case-By-Case

b. Allowances for Subdivisions and Multiple Occupancy Projects
Developers of Subdivisions and Multiple Occupancy Projects will receive a $3,360.00
aAllowance for each single phase transformer installed within a development and a
$6,890.00 aAllowance for each three phase transformer installed within a development.
Subdividers will be eligible to receive aAllowances for Line Installations Terminal Facilities
installed inside residential and non-residential subdivisions.

Idaho Power Company Original Sheet No H-12
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. H-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– November 27, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 December 1, 2009 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

8. Refunds

a. Vested Interest Refunds. Vested Interest Refunds will be paid by the Company and
funded by the Additional Applicant's Vested Interest Charge as calculated in accordance
with Section 5. The initial Applicant will be eligible to receive refunds up to 80 percent of
their original construction cost. Additional Applicants that become Vested Interest
Holders will be eligible to receive refunds up to their total contribution less 20 percent of
the original construction cost.

A Vested Interest Holder and the Company may agree to waive the Vested Interest
payment requirements of Additional Applicants with loads less than an agreed upon level.
Waived Additional Applicants will not be considered Additional Applicants for purposes of
Section 8.a.i. (1) below.

i. Vested Interest Refund Limitations

(1). Vested Interest Refunds will be funded by no more than 4 Additional
Applicants during the 5-year period following the completion date of the
Line Installation for the initial Applicant.

(2). In no circumstance will refunds exceed 100 percent of the refundable
portion of any party's cash payment to the Company.

b. Subdivision Refunds.

i. Applicants will be eligible for Vested Interest Refunds for facilities installed inside
Subdivisions if the construction was NOT part of the initial Line Installation.
Customers requesting additional Line Installations within a Subdivision will be
considered new Applicants and become eligible for Vested Interest Refunds.

ii. A subdivider will be eligible for Vested Interest Refunds for payments for Line
Installations outside subdivisions.

Idaho Power Company Original Sheet No. H-13
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. H-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– November 27, 2009John R. GaleTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 December 1, 2009 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

9. Local Improvement Districts

Unless specifically provided for under this paragraph, a Local Improvement District will be
provided service under the general terms of this rule.

The Company will provide a cost estimate and feasibility study for a Local Improvement District
within 120 days after receiving the resolution from the requesting governing body. The Cost
Quote will be based on Work Order Costs and will not be considered binding on the Company if
construction is not commenced within 6 months of the submission of the estimate for reasons not
within the control of the Company. The governing body issuing the resolution will pay the
Company for the costs of preparing the cost estimate and feasibility study regardless of whether
the Line Installation or Alteration actually takes place.

After passage of the Local Improvement District ordinance, the Company will construct the Line
Installation or Alteration. Upon completion of the project, the Company will submit a bill to the
Local Improvement District for the actual cost of the work performed, including the costs of
preparing the cost estimate and feasibility study. If the actual cost is less than the estimated
cost, the Local Improvement District will pay the actual cost. If the actual cost exceeds the
estimated cost, the Local Improvement District will pay only the estimated cost. The governing
body will pay the Company within 30 days after the bill has been submitted.

A Local Improvement District will be eligible for an Line Installation Allowance for any new load
connecting for service upon the completion of the Line Installation. A Local Improvement District
will retain a Vested Interest in any Line Installation to the Local Improvement District. A Local
Improvement District may waive payments for Vested Interest from Additional Applicants within
the Local Improvement District.

Idaho Power Company Second RevisedOriginal Sheet No. H-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. H-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32592 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 July 12, 2012 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

10. Relocations in Public Road Rights-of-Way

The Company often locates its distribution facilities within state and local public road rights-of-
way under authority of Idaho Code § 62-705 (for locations outside Idaho city limits) and the
Company’s city franchise agreements (for locations within Idaho city limits). When the Company
is notified of a road improvement project pursuant to Idaho Code § 40-210, the Company will meet
with the Public Road Agency as provided in Idaho Code to § 40-210.

If a Public Road Agency determines that the Company’s facilities incommode the public use of
any road, highway, or street, the Public Road Agency can require the company to relocate or
remove the facilities. If a Public Road Agency determines that the Company’s facilities must be
relocated or removed because they incommode the public use of the road, highway, or street, the
Company will relocate its distribution facilities from or within the public road rights-of-way and the
Company will bear the costs of such relocation.

If one or more Private Beneficiaries has requested that the Company’s facilities be relocated or
removed, the Company will use reasonable efforts to recover that portion of the total Relocation
or removal costs attributable to the request from the Private Beneficiaries. If the Private
Beneficiaries dispute the Company’s calculation of the Private Beneficiaries’ cost responsibility,
either the Company or the affected Private Beneficiaries may initiate a proceeding to have the
Commission establish the reasonableness of the Company’s calculation of the Relocation or
removal cost responsibility as between the Company and the Private Beneficiaries.

11. Existing Agreements

This rule shall not cancel existing agreements, including refund provisions, between the Company
and previous Applicants, or Additional Applicants. All Applications will be governed and
administered under the rule or schedule in effect at the time the Application was received and
dated by the Company.

Idaho Power Company Second RevisedOriginal Sheet No. I-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. I-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS

1. Residential Budget Pay Plan - Schedules 1, 4, 5, and 6. A Budget Pay Plan is available
to Residential Customers desiring to levelize payments for electric service. If a Customer has more than
one electric service on the account, each electric service charge will be levelized individually. A
Customer may sign up for the Budget Pay Plan at any time during the year. In order to be eligible for the
Budget Pay Plan, the Customer’s account must not be in arrears and the customer must have received
service at the same location for a minimum of nine months.

The levelized payment will approximate the average of 12 monthly billings based on either the
historical charges, or an estimate of future charges. The Budget Pay amount for each electric service
on the account will be adjusted to the next higher dollar. Budget Pay amounts will be recalculated at
the 12-month (or 365-day) anniversary of the first bill that was generated after the Customer enrolled in
the Budget Pay Plan. The new monthly payment will be the recalculated Budget Pay amount(s). A
Customer’s Budget Pay amount(s) may decrease, increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers
with a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination
of the agreement after all charges for services have been paid, will be refunded at the Customer’s
request. If no request for refund is made, the monthly Budget Pay charges will be equal to the
recalculated Budget Pay amount reduced by one-twelfth of the positive balance. Upon the Customer’s
request, a positive balance for one Budget Pay electric service may be transferred to the balance of
another Budget Pay electric service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once
established, the Budget Pay Plan will remain in effect from year to year until the Customer notifies the
Company not less than 30 days prior to the desired date of cancellation or unless the Customer fails to
pay the agreed amounts.

2. Small General Service Budget Pay Plan - Schedules 7 and 8. A Budget Pay Plan is
available to Small General Service Customers receiving service on Schedules 7 and 8. If a Customer
has more than one electric service on the account, each electric service charge will be levelized
individually. If a Customer transfers to another schedule (other than Schedules 1, 4, 5, or 6), the Budget
Pay Plan will not be available. A Customer may sign up for the Budget Pay Plan at any time during the
year.

In order to qualify, the Customer must have been receiving service at the same location, under the
same ownership and account number, and with all monthly billings paid on or before the past due date for
at least 12 months prior to applying for the Budget Pay Plan. The Customer must maintain the payment
status as described above or the Customer will be removed from the Budget Pay Plan on the next
monthly billing and all past due balances will become immediately due and payable.
Idaho Power Company Second RevisedOriginal Sheet No. I-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. I-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS
(Continued)

2. Small General Service Budget Pay Plan - Schedules 7 and 8 (Continued)

The levelized payment will approximate the average of 12 monthly billings based on historical
charges. Budget Pay amounts will be recalculated at the 12-month (or 365-day) anniversary of the first
bill that was generated after the Customer enrolled in the Budget Pay Plan. The Budget Pay amount for
each electric service on the account will be adjusted to the next higher dollar. The new monthly payment
will be the recalculated Budget Pay amount(s). A Customer’s Budget Pay amount(s) may decrease,
increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers
with a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination
of the agreement after all charges for services have been paid, will be refunded at the Customer’s
request. If no request for refund is made, the monthly Budget Pay charges will be equal to the
recalculated Budget Pay amount reduced by one-twelfth of the positive balance. Upon the Customer’s
request, a positive balance for one Budget Pay electric service may be transferred to the balance of
another Budget Pay electric service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once
established, the Budget Pay Plan will remain in effect from year to year until the Customer notifies the
Company not less than 30 days prior to the desired date of cancellation or unless the Customer fails to
pay the agreed amounts.

Idaho Power Company First Revised Original Sheet No. J-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. J-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35263 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 December 20, 2021 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

1. Electric Service is inherently subject to occasional interruption, suspension, curtailment,
and fluctuation. The Company designs and operates its system in conformance with the service voltage
ranges described in the current edition of standard C84.1 of the American National Standards Institute –
American National Standard for Electric Power Systems and Equipment – Voltage Ratings (60HZ) and
will have no liability to its Customers or any other persons for any interruption, suspension, curtailment, or
fluctuation in service or for any loss or damage caused thereby if such interruption, suspension,
curtailment, or fluctuation results from any of the following:

a. Causes beyond the Company's reasonable control including, but not limited to,
fire, flood, drought, winds, acts of the elements, court orders, insurrections or riots, generation
failures, lack of sufficient generating capacity, breakdowns of or damage to facilities of the
Company or of third parties, acts of God or public enemy, strikes or other labor disputes, civil,
military or governmental authority, electrical disturbances originating on or transmitted through
electrical systems with which the Company's system is interconnected, and acts or omissions of
third parties;

b. Repair, maintenance, improvement, renewal or replacement work on the
Company's electrical system, which work in the sole judgment of the Company is necessary or
prudent; to the extent practicable work shall be done at such time as will minimize inconvenience
to the Customer and, whenever practicable, the Customer shall be given reasonable notice of
such work;

c. Automatic or manual Aactions taken by the Company, including, but not limited to,
load curtailment, which in its sole judgment are necessary or prudent to protect the performance,
integrity, reliability or stability of the Company's electrical system or any electrical system with
which it is inter-connected, which actions may occur automatically or manually.

2. The provisions of this rule do not affect any person’s rights in tort.

3. Load curtailment and interruption carried out in compliance with an order by governmental
authority shall follow the Company’s plan entitled "Load Curtailment and Interruption Plan", as outlined
below.
Idaho Power Company Original Sheet No. J-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. J-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35263 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 December 20, 2021 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

LOAD CURTAILMENT AND INTERRUPTION PLAN:

OVERVIEW

1. The Company will comply with all state and federal mandates to curtail the electric
energy used by its Customers to prevent an electrical system collapse. Events that may trigger load
curtailment, either upon notice from state agencies, the Regional Reliability Coordinator, or at the
discretion of the Company, include but are not limited to:

a. Fire, flood, drought, winds, generation failures, lack of sufficient generating capacity,
equipment failures, governmental authority,

b. Actions taken to protect the performance, integrity, reliability or stability of the
Company's electrical system or any electrical system to which it is interconnected, which
actions may occur automatically or manually,

c. Actions taken by the Company that in its sole judgment are necessary or prudent for the
safety of people and/or equipment, or

d. Cyber-attacks or software failure of any part of the Company’s generation, transmission,
and/or distribution system protection and/or control systems.

2. Load curtailment can last for a short amount of time, but also could last for hours or even
days.

AUTOMATIC, REMOTE AND MANUAL ACTIONS

1. Automatic actions occur through the operation of programmed protective equipment
installed on the Company's electrical system, including, without limitation, equipment such as automatic
relays, generator controls, circuit breakers, and switches. This protection equipment is preset to
operate under certain prescribed conditions that, in the sole judgment of the Company, threaten system
performance, integrity, reliability or stability.

2. Where Supervisory Control and Data Acquisition (SCADA) equipment is installed, the
Company will remotely control switches, circuit breakers, relays, voltage regulators or other equipment.
In areas where no SCADA equipment is installed, actions are performed manually by on-site field
personnel.

3. If actions are undertaken, then to the extent permitted by the operating characteristics of
the electrical system, the Company will perform such actions so that interruption, curtailment, or
fluctuation of service to customers will be accomplished sequentially, unless it is necessary in the sole
judgment of the Company, or if required by the Regional Reliability Coordinator to vary said sequence
in order to protect system performance, integrity, reliability or stability.
Idaho Power Company Original Sheet No. J-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. J-3

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35263 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 December 20, 2021 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

CURTAILMENT AND INTERRUPTION

1. Curtailment and/or interruption of electric service can occur at any time for a multitude of
situations. When these situations arise, Idaho Power intends to take appropriate actions to mitigate the
situation for reliability while maintaining service continuity to as many customers as practical.
Depending on the nature of the situation, mitigation actions will range from actions that will not affect
Customers to actions that curtail and/or interrupt service, impacting localized areas and/or the entire
Idaho Power service area.

2. Idaho Power will promptly notify and keep state regulatory and reliability authorities
informed of the curtailment and/or interruption to electric service.

ROTATING OUTAGES AND ONGOING CURTAILMENT

1. Curtailment and/or interruption of Customer load may be necessary to maintain the
reliability of the electric system in certain situations. In the event Idaho Power must curtail or interrupt
Customer load for any reason, the Company’s intent is to curtail the appropriate amount of load
necessary to mitigate the situation. This is accomplished by selecting the amount or percent of load
reduction needed in the Energy Management System (EMS) Load Shedding application. The EMS
Load Shedding application allows the operator to select the applicable localized area or necessary
portions of the Company’s service area to curtail the load. Load curtailment is accomplished manually
in areas that do not have SCADA connected to the EMS.

2. A range of curtailment stages associated with increasing levels of energy deficiencies
has been developed, incorporating North American Electric Reliability Corporation (NERC) standards.
The circumstances necessitating a reduction in the consumption of electricity in the short term will
normally require that immediate emergency action is taken and as such there may be little or no
warning. Sudden equipment outages or loss of generation could potentially lead directly to any
curtailment stage without prior notice or progression of the stages described below. These stages align
with the severity of the energy deficiency and are intended to minimize customer impact.
Idaho Power Company Original Sheet No. J-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. J-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35263 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 December 20, 2021 1221 West Idaho Street, Boise, Idaho

RULE J
CONTINUITY, CURTAILMENT AND
INTERRUPTION OF ELECTRIC
SERVICE

ROTATING OUTAGES AND ONGOING CURTAILMENT (Continued)

Stage Nature Type of Curtailment
1 All generation resources are committed.
Firm Customer load, firm transactions,
and reserve commitments are met.
Concerned about sustaining required
Contingency Reserves
 Non-firm wholesale energy sales
 Ask Customers to voluntarily take
conservation measures  
 Issue communications notifying
employees of the situation and asking
Company departments to reduce internal
utility energy use. 
2 Idaho Power is no longer able to
provide expected energy requirements
 Curtailment actions listed in Stage 1
 Interruptible Customer load and available
demand response programs
 Issue communications requesting
government agencies to implement their
programs to achieve necessary energy
reductions
3 Idaho Power is unable to meet minimum
Contingency Reserves as required by
NERC Standards
 Curtailment actions listed in Stage 1 and
Stage 2
 Implement Emergency Load Shed and
Block Rotation
4 Emergency Load Shed due to
immediate risk posed to electrical
reliability.
 Applicable to all Customers. May be
limited to a specific location if reliability risk
is local to an area.

3. Demand response programs, if deployed as a required action under this plan, will not be
operated under the provisions of Schedules 23, 81, and 82. The provisions of Schedules 23, 81, and
82, including but not limited to operating hours, notification requirements, and incentive payments will
not apply for any time period that the Company utilizes a Load Control Device installed under the
programs to interrupt a participating customer’s load for an electric system emergency.

RETURN TO SERVICE

Idaho Power will return service to its Customers when:
 The Company can meet its load and required operating reserves.
 The reliability of the electric system will not be jeopardized.
 Reliability Coordinator approval has been received, if applicable.

Idaho Power Company Second RevisedOriginal Sheet No. K-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. K-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – September 15, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 October 17, 2022 1221 West Idaho Street, Boise, Idaho
Advice No. 22-02

RULE K
CUSTOMER'S LOAD AND
OPERATIONS

1. Interference with Service. The Company reserves the right to refuse to supply loads of a
character that may seriously impair service to any other Customers, or may disconnect existing service
if it is seriously impairing service to any other Customers. In the case of pump hoist or elevator motors,
welders, furnaces, compressors, and other installations of like character where the use of electricity is
intermittent, subject to voltage fluctuations, voltage notching or draws a non-sinusoidal (harmonically
distorted) load current, the Company may require the Customer to provide equipment, at the
Customer's expense, to reasonably limit such fluctuations.

2. Practices and Requirements for Harmonic Control. Customers are required to comply
with the Standard for Harmonic Control in Electric Power Systems as set forth in the current Institute of
Electrical and Electronic Engineers (IEEE) Standard 519. The values indicated by IEEE Standard 519
apply at the point where the Company’s equipment interfaces with the Customer’s equipment.

3. Change of Load Characteristic. The Customer shall give the Company prior notice
before making any significant change in either the amount or electrical character of the Customer’s
electrical load thereby allowing the Company to determine if any changes are needed in the Company’s
equipment or distribution system. The Customer may be held liable for damages to the Company’s
equipment resulting from the Customer’s failure to provide said notice of change in electrical load.

4. Protection of Electrical Equipment. The Customer is solely responsible for the selection,
installation, and maintenance of all electrical equipment and wiring (other than the Company's meters
and apparatus) on the load side of the Point of Delivery. The Customer should provide adequate
protection for equipment, data, operations, work and property under the Customer’s control from
system disturbances such as (a) high and low voltage, (b) surges, harmonics, and transients in voltage,
and (c) overcurrent. For unidirectional and three-phase equipment, the Customer should provide
adequate protection from “single phasing conditions”, reversal of phase rotation, and phase unbalance.

5. Motor Installations. The Company reserves the right to refuse single phase service to
motors larger than 7 ½ horsepower.

a. Motor Connection. All motor installations greater than 7 ½ horsepower (HP)
must be approved by the Company to determine how the motor’s connection will affect the
Company’s system. Changes to Company facilities necessary to address the effects of, but not
limited to, flicker, voltage balance, voltage level, or reactive power may be at the Customer’s
expense.

Idaho Power Company Original Sheet No. K-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. K-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

RULE K
CUSTOMER'S LOAD AND
OPERATIONS
(Continued)

5. Motor Installations (Continued)

b. Allowable Motor Starting Currents. The starting currents (as determined by tests
or based on published data by manufacturers) of alternating current motors will not exceed the
allowable locked rotor current values shown in the following table, corrections being allowed to
compensate for the difference between the voltage supply at the motor terminals and its rated
voltage. If the starting current of the motor exceeds the locked rotor current value indicated by
the table below, a starter must be used or other means employed to limit the starting current to
the locked rotor current value specified, except that such starting equipment may be omitted by
written permission of the Company where the absence of such starting equipment will not cause
objectionable voltages. Maximum permissible locked rotor current values in the following table
apply to a single motor installation. Starters may be omitted on the smaller motors of an
installation consisting of more than one motor when their omission will not result in a current in
excess of the allowable locked rotor current of the single largest motor of the group.

llowable Locked Rotor Currents*
Single-Phase Motors Three-Phase Motors
208 Volt 240 Volt 208 Volt 240 Volt 480 Volt Over 480 Volt
Rated Size HP Starting Amps llowed
7.5 127 110
10 163 141 71
15 227 197 99
20 288 250 125
25 351 304 152
30 415 360 180
40 438 380 190
50 462 400 200
60 554 480 240
75 692 600 300
Over 75

*Note: If no value is shown, Company approval of the locked rotor current is required prior to
motor installation.

Idaho Power Company First RevisedOriginal Sheet No. L-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. L-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – August 14, 2018per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 September 18, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 18-01

RULE L
DEPOSITS

1. Residential and Small Commercial Customers. Unless otherwise specified in another rule,
the Company’s practices relating to deposits are governed by the Utility Customer Relations Rules
(UCRRs) of the Idaho Public Utilities Commission, in effect at the time the event occurred which required
application of the UCRRs.

2. Large Commercial and Special Contract Customers. The Company may require a
deposit from Large Commercial or Special Contract Customers as follows:

a. Existing Customers. A deposit may be required for failure to pay the amount due
on or before the date the bill is delinquent, the risk of future loss is evident based on the
Customer’s current commercial credit rating, or the Company becomes aware the Customer’s
business activities are speculative or subject to a high rate of failure. Evidence of a high rate of
failure may include, but is not limited to, elevated risk of bankruptcy.

b. Applicants. A deposit may be required under the following conditions:

i. If the nature of the applicant’s business is speculative or subject to a high
rate of failure; or

ii. The applicant is applying for service with the Company for the first time;
or

iii. The applicant has an outstanding prior service account with the Company
that accrued within the last four years and at the time of application for service remains
unpaid and not in dispute; or

iv. The applicant fails to pass an objective commercial credit screen.

c. Written Explanation for Denial of Service or Requirement of Deposit. If the
Company denies service or requires a cash deposit as a condition of providing or continuing
service, then it will immediately provide a written explanation to the applicant or Customer
stating the reasons why it denies service or requires a deposit. The applicant or Customer will
be given an opportunity to rebut those reasons.

d. Amount of Deposit. The amount of the deposit shall not exceed two times the
Customer’s or applicant’s actual or estimated highest monthly bill. The deposit may be paid in
two equal installments; the first installment must be paid at the time of the application for service
or upon notice from the Company to Existing Customers, and the second installment must be
paid within 30 days.

e. Interest on Deposits. Interest on deposits held by the Company shall be accrued
at the rate established by the Commission specified in IDAPA 31.21.01 Rule 106. Interest shall
be computed from the time the deposit is made until it is refunded or applied to the Customer’s
regular bill. Interest will not accrue on a deposit if service is discontinued temporarily at the
request of a Customer who leaves the deposit with the Company for future use as a deposit, or
if service has been permanently discontinued and the Company has been unsuccessful in its
attempt to refund a deposit.

Idaho Power Company First RevisedOriginal Sheet No. L-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. L-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– August 14, 2018 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 September 18, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 18-01

RULE L
DEPOSITS
(Continued)

2. Large Commercial and Special Contract Customers (Continued)

f. Retention During Dispute. The Company may retain the deposit pending the
resolution of a dispute over termination of service. If the deposit is later returned to the
Customer, the Company shall pay interest at the annual rates established in IDAPA 31.21.01
Rule 106 for the entire period over which the deposit was held.

g. Transfer of Deposit. Deposits shall not be transferred from one Customer to
another Customer or between classes of service, except at the Customer’s request. When a
Customer with a deposit on file transfers service to a new location within the Company’s service
area, the deposit and any outstanding balance shall be transferred to the account for the new
location.

h. Bankrupt Customers. If an applicant for service or a Customer has sought any
form of relief under the Federal Bankruptcy Laws, has been brought within the jurisdiction of the
bankruptcy court for any reason in an involuntary manner, or has had a receiver appointed in a
state court proceeding, then a deposit may be required as a condition of service.

i. Refunding Deposits. The Company will may retain deposits for a minimum of
twelve calendar months. If the Customer has established good credit with the Company at the
end of twelve months, or sooner, in the Company’s sole discretion, the original deposit amount
along with any accrued interest will be applied as a credit to the Customer’s current account or
refunded. Whenever a Customer does not establish good credit with the Company at the end of
the first twelve months, the deposit will be retained and the Customer’s credit history will be
evaluated every twelve months until good credit has been established. If a Customer‘s
business activities have been determined to be speculative or subject to a high rate of failure,
the Company may retain the deposit beyond twelve months. In such instances, the need for a
deposit will be evaluated every twelve months until the Customer passes an objective
commercial credit screen.

Idaho Power Company First RevisedOriginal Sheet No. M-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. M-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – August 7, 2015per Order No.Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 September 7, 2015 1221 West Idaho Street, Boise, Idaho
Advice No. 15-09

RULE M
FACILITIES CHARGE SERVICE

This rule applies to eligible customers taking Primary or Transmission Service under Schedules
9, 19 or Special Contract, or Transmission Service under Schedule 24. Eligible Customers may
request that the Company design, install, own, and operate transformers and other facilities beyond the
Point of Delivery that are solely provided to meet the Customer’s service requirements. This service is
provided at the Customer’s request and at the option of the Company in exchange for the Customer
paying a monthly facilities charge to the Company. Primary and Transmission Service level Customers
not taking facilities charge services are responsible for providing the transformation of power beyond
the Point of Delivery needed to meet the Customer’s service requirements. See Rule B.

1. Company-Owned Facilities Beyond the Point of Delivery

Under a facilities charge arrangement, the Company will own and operate facilities beyond the
Point of Delivery that are installed to solely benefit the Customer, and the Customer will pay a
monthly facilities charge to the Company based on a percentage of the initial total investment
cost of the facilities installed. As part of this arrangement, the Customer agrees to allow Idaho
Power access to the Customer’s property to provide installation of facilities, operation and
maintenance, alteration, relocation, upgrade, conversion, and/or removal in order to meet the
Customer’s service requirements. The Customer agrees to provide rights-of-way as outlined in
Rule C.

Company-owned facilities beyond the Point of Delivery will be set forth in a Distribution Facilities
Investment Report (DFI) provided to the Customer. As the Company’s investment in facilities
beyond the Point of Delivery changes in order to meet the Customer’s service requirements, the
Company shall notify the Customer of the additions and/or deletions of facilities by forwarding
toproviding the Customer a revised DFI. The Company will also adjust the monthly facilities
charge to be paid by the Customer based on any increase or decrease in the investment cost of
the Company-owned facilities resulting from additions and/or deletions as set forth in the revised
DFI.

2. Alteration and Failure of Company-Owned Facilities

In the event the Customer requests the Company to alter (remove, reinstall, or change)
Company-owned facilities beyond the Point of Delivery, the Customer shall pay to the Company
the “non-salvable cost” of such removal, reinstallation, or change. Non-salvable cost as used
herein is comprised of the total depreciated costs of materials, labor, and overheads of the
facilities, less the difference between the salvable cost of material removed, and removal labor
cost including appropriate overhead costs.

Failed equipment will be replaced by the Company as part of providing ongoing operation and
maintenance of Company-owned facilities installed beyond the Point of Delivery. When a failed
piece of equipment is replaced by the Company, the initial investment cost of the failed piece of
equipment will be removed from the Customer’s DFI and replaced with the investment cost of
the new piece of equipment to calculate the Customer’s monthly facilities charge.

Idaho Power Company First RevisedOriginal Sheet No. M-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. M-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33514 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 July 16, 2016 1221 West Idaho Street, Boise, Idaho

RULE M
FACILITIES CHARGE SERVICE

3. Sale of Company-Owned Facilities

Customers paying a facilities charge may request to purchase Company-owned facilities
installed beyond the Point of Delivery. All sales of facilities must meet the following provisions:

a. No mixed ownership of facilities. A Customer purchasing Company-owned facilities
installed beyond the Point of Delivery must purchase all facilities listed on the DFI for
that location.

b. The Customer must provide the operation and maintenance of all facilities installed
beyond the Point of Delivery after the sale is complete.

c. The Customer must prepay engineering costs for sales determinations taking greater
than 16 estimated hours of preparation. Sales determinations equal to or less than 16
estimated hours of preparation will be billed to the Customer as part of the sales
agreement, or after the engineering is completed in instances where the sale is not
finalized.

The factors set forth in Idaho Code § 61-328(3) will be considered as a guide for the sale of
Company-owned facilities installed beyond the Point of Delivery to the customer served by
those facilities. All sales shall be brought before the Commission, whether as an application or
other informal procedure.

4. Monthly Facilities Charge Rate

Effective January 1, 2012, a A facilities charge, as specified in Schedule 66, will be assessed on
each facilities charge customer’s monthly billing, regardless of the quantity of energy consumed,
until either another Customer requests to assume responsibility for such facilities charge
arrangement, which may be allowed at the option of the Company, or the facilities charge
customer pays to the Company the non-salvable cost associated with the removal of all
Company-owned facilities beyond the Point of Delivery.

5. Consent and Acknowledge Form

Prior to entering into a facilities charge arrangement, the Customer and Company must agree to
and sign the Facilities Charge Service Consent and Acknowledgement Form attached to this
rule.

Idaho Power Company First RevisedOriginal Sheet No. M-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. M-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– February 24, 2012Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 24, 2012 1221 West Idaho Street, Boise, Idaho
Advice No. 12-04

RULE M
FACILITIES CHARGE SERVICE

Idaho Power Company
Facilities Charge Service
Consent and Acknowledgement Form

By signing this form, Idaho Power Company (“Idaho Power”) and __________________
(“Customer”) hereby consent to and acknowledge the following:

1. Idaho Power will design, install, own, and operate transformers and other facilities on the
Customer’s property which are beyond Idaho Power’s Point of Delivery and are solely provided to meet
the Customer’s service requirements at the following Customer location:

____________________________________________________________________________

2. This service is provided at the Customer’s request and at the option of Idaho Power in
exchange for the Customer paying a monthly facilities charge to Idaho Power as specified in Schedule
66 of Idaho Power’s current and effective tariff.

3. Idaho Power and the Customer agree that this arrangement is provided under the terms
and conditions of Rule M, Facilities Charge Service, of Idaho Power’s current and effective tariff.

Dated: _____________________

IDAHO POWER COMPANY CUSTOMER

_________________________ _________________________

PRINT NAME PRINT NAME

TITLE TITLE

Idaho Power Company Second RevisedOriginal Sheet No. 1-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 1-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– January 19, 2012Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 March 1, 2012 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02

SCHEDULE 1
RESIDENTIAL SERVICE
STANDARD PLAN

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served, and additional investment by the Company for new transmission,
substation or terminal facilities is not necessary to supply the desired service.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate general service schedule
will apply. However, if the wiring is so arranged that the service for residential purposes can be metered
separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on SeptemberOctober 1 of each year and ends on May 31 of
each year.

WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc. and the
Company. The installation of the water heating equipment shall conform to all National, State, and
Municipal Codes. No single electric water heating unit shall exceed 6 kW; and where two or more
Idaho Power Company Second RevisedOriginal Sheet No. 1-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 1-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– January 19, 2012Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – January 1, 2024 March 1, 2012 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02
heating units are used, these units shall be so interlocked that not more than 6 kW can be connected at
any one time.

Where electric water heaters not complying with these specifications are installed, the Customer will be
required to pay the original installation or upgrade costs for any nonstandard facilities needed to supply
the electrical capacity to meet the water heater demand. Water heating equipment must not impair or
interfere with service to any other customer
Idaho Power Company Eighteenth RevisedOriginal Sheet No. 1-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventeenth Eighteenth Revised Sheet No. 1-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 1
RESIDENTIAL SERVICE
STANDARD PLAN
(Continued)

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single-phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of 2 kW or larger
shall be controlled by approved thermostatic devices. When a group of heating units, with a total capacity
of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so designed
that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-type heaters,
that may be used with a heat exchanger, shall comply with the specifications listed above for such units.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $5.0010.00 $5.0010.00

Energy Charge, per kWh
First 800 kWh 8.651810.1082¢ 8.03908.8958¢
801-2000 kWh 10.403312.1546¢ 8.86279.8073¢
All Additional kWh Over 2000 12.358514.4385¢ 9.815410.8615¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company First RevisedOriginal Sheet No. 3-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 3-1
IDAHO Issued by IDAHO POWER COMPANY
Issued August 24, 2010per Order No. Gregory W. SaidTimothy E. Tatum, General ManagerVice
President, Regulatory Affairs
Effective – September 27, 2010January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 10-02

SCHEDULE 3
MASTER-METERED MOBILE HOME PARK
RESIDENTIAL SERVICE

AVAILABILITY

Service under this schedule is available to master-metered mobile home parks included on the
Company’s list of “grandfathered” mobile home parks on file with the Idaho Public Utilities Commission
receiving electric service under Schedule 1 as of March 20, 2009. Customers included on the Company’s
list of “grandfathered” mobile home parks as of March 20, 2009 will automatically be transferred to this
Schedule on their next regularly scheduled cycle read date that occurs on or after March 21, 2009.

APPLICABILITY

Service under this schedule is applicable to Electric Service provided to a master-metered
residential mobile home park for residential service for general domestic uses, including single phase
motors of 7½ horsepower rating or less. This schedule is not applicable to standby service or shared
service.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit):

Service Charge, per month $5.0010.00

Energy Charge, per kWh
all kWh 8.707510.3844¢

Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Energy Charge, and
the Power Cost Adjustment.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc. and the
Company. it’s the installation of the water heating equipment shall conform to all National, State, and
Municipal Codes.. No single electric water heating unit shall exceed 6 kW; and where two or more heating
Idaho Power Company First RevisedOriginal Sheet No. 3-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 3-1
IDAHO Issued by IDAHO POWER COMPANY
Issued August 24, 2010per Order No. Gregory W. SaidTimothy E. Tatum, General ManagerVice
President, Regulatory Affairs
Effective – September 27, 2010January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 10-02
units are used , these units shall be so interlocked that not more than 6 kW can be connected at any one
time.

Where electric water heaters not complying with these specifications are installed, the Customer
will be required to pay the original installation or upgrade costs for any nonstandard facilities needed to
supply the electrical capacity to meet the water heater demand. Water heating equipment must not impair
or interfere with service to any other customer.

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of two kW or
larger shall be controlled by approved thermostatic devices. When a group of heating units, with a total
capacity of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so
designed that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-
type heaters, that may be used with a heat exchanger, shall comply with the specifications listed above
for such units.
Idaho Power Company Fourteenth RevisedOriginal Sheet No. 3-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101Thirteenth First Revised Sheet No. 3-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 3
MASTER-METERED MOBILE HOME PARK
RESIDENTIAL SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit):

Service Charge, per month $5.00

Energy Charge, per kWh
all kWh 8.7075¢

Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Energy Charge, and
the Power Cost Adjustment.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Second Revised Sheet No. 4-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 4-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – January 19, 2012 Gregory W. Said, Vice President, Regulatory Affairs
Effective – March 1, 2012 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02

SCHEDULE 4
RESIDENTIAL SERVICE
ENERGY WATCH PILOT PLAN
(OPTIONAL)
SUSPENDED

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system to
residential Customers in the Emmett Valley where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the Premises to be served, additional investment by the Company
for new transmission, substation or terminal facilities is not necessary to supply the desired service, and
Advanced Meter Reading (AMR) equipment is installed. For the purposes of this schedule, the Emmett
Valley is considered to be the area within the vicinity of the cities of Emmett and Letha, Idaho.

The Residential Service Energy Watch Pilot Plan is an optional, voluntary service that provides
residential Customers the option to take electric service with a critical peak pricing component.

If a Customer requests to participate in this Pilot, the Customer will be placed on the rate
schedule at the next regularly scheduled meter reading provided the Company has received two weeks
notice from the Customer prior to the next regularly scheduled meter read date, subject to work
schedule constraints.

A Customer may terminate their participation on this rate schedule at any time. However, the
Customer may not subsequently elect service under this rate schedule for one year after the effective
date of cancellation.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate general service
schedule will apply. However, if the wiring is so arranged that the service for residential purposes can
be metered separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service
Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

The Company shall have the right to select and reject Pilot participants at its sole discretion.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery.
Upon request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for
multi-family dwellings when all equipment is U L approved to operate at 120/208 volts.
Idaho Power Company Fourth Revised Sheet No. 4-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 4-2
IDAHO Issued by IDAHO POWER COMPANY
Issued – January 19, 2012 Gregory W. Said, Vice President, Regulatory Affairs
Effective – March 1, 2012 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02

SCHEDULE 4
RESIDENTIAL SERVICE
ENERGY WATCH PILOT PLAN
(OPTIONAL)
SUSPENDED
(Continued)

WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc. and the
Company. The installation of the water heating equipment shall conform to all National, State, and
Municipal Codes. No single electric water heating unit shall exceed 6 kW; and where two or more
heating units are used, these units shall be so interlocked that not more than 6 kW can be connected at
any one time.

Where electric water heaters not complying with these specifications are installed, the Customer
will be required to pay the original installation or upgrade costs for any nonstandard facilities needed to
supply the electrical capacity to meet the water heater demand. Water heating equipment must not
impair or interfere with service to any other customer.

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of two kW or
larger shall be controlled by approved thermostatic devices. When a group of heating units, with a total
capacity of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so
designed that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-
type heaters, that may be used with a heat exchanger, shall comply with the specifications listed above
for such units.

ENERGY WATCH EVENT

All times are stated in Mountain Time. An Energy Watch Event is a four-hour period between
the hours of 5:00 p.m. and 9:00 p.m. on weekdays, excluding Independence Day when it falls on a
weekday, between June 15 and August 15. During an Energy Watch Event the price per kWh is set at
a higher level than the price per kWh at all other hours in order to provide a price signal for Customers
to shift energy usage off of the four-hour period. The Company will declare an Energy Watch Event at
its sole discretion. No more than 10 Energy Watch Events will be declared between June 15 and
August 15, for a total of no more than 40 Energy Watch Event hours. The Company will contact
Customers taking service under this schedule by 4:00 p.m. the day before an Energy Watch Event is to
occur.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.
Idaho Power Company Sixteenth Revised Sheet No. 4-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Fifteenth Revised Sheet No. 4-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 4
RESIDENTIAL SERVICE
ENERGY WATCH PILOT PLAN
(OPTIONAL)
SUSPENDED
(Continued)

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 1:00 p.m. to 9:00 p.m. Monday through Friday
Off-Peak: 9:00 p.m. to 1:00 p.m. Monday through Friday and all hours on weekends and
holidays
Critical peak period (10 select summer days): 5:00 p.m. to 9:00 p.m.

Non-summer Season
Mid-Peak: 7:00 a.m. to 9:00 p.m. Monday through Friday
Off-Peak: 9:00 p.m. to 7:00 a.m. Monday through Friday and all hours on weekends and
holidays

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit).

Service Charge, per month $5.00

Energy Charge, per kWh

Summer
Energy Watch Event hours 43.8454¢

On-Peak 12.3072¢
Off-Peak 7.0679¢

Non-summer
Mid-Peak 9.0927¢
Off-Peak 7.0679¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company Fourth RevisedOriginal Sheet No. 5-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 5-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – August 21, 2015Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – October 1, 2015January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 15-10

SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-DAY PILOT USE PLAN
(OPTIONAL)

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho to residential Customers where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the Premises to be served, additional investment by the Company for
new transmission, substation or terminal facilities is not necessary to supply the desired service, and
Advanced Meter Reading (AMR) equipment is installed. Idaho Power reserves the right to limit
participation in this pilot plan at the Company’s discretion.

The Residential Service Time-of-Day PilotUse Plan is an optional, voluntary service that provides
residential Customers the option to take electric service with seasonal time-of-day use energy rates.

If a Customer requests to participate in this pilot schedule, the Customer will be placed on the
schedule effective with their next billing cycle.

A Customer may terminate their participation on this schedule at any time. However, the
Customer may not subsequently elect service under this schedule for one year after the effective date of
cancellation. If a Customer requests to be taken off of the schedule, the Customer will be removed from
the schedule as of the last meter read date.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate general service schedule
will apply. However, if the wiring is so arranged that the service for residential purposes can be metered
separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

The Company shall have the right to select and reject Pilot participants at its sole discretion.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.

SUMMER AND NON-SUMMER SEASONS
Idaho Power Company Fourth RevisedOriginal Sheet No. 5-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 5-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – August 21, 2015Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – October 1, 2015January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 15-10

The summer season begins on June 1 of each year and ends on September 30 of each year.
The non-summer season begins on October 1 of each year and ends on May 31 of each year.
Idaho Power Company Third RevisedOriginal Sheet No. 5-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 5-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– January 19, 2012Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – March 1, 2012January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02

SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-DAY PILOTUSE PLAN
(OPTIONAL)
(Continued)

WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc. and the
Company. The installation of the water heating equipment shall conform to all National, State, and
Municipal Codes. No single electric water heating unit shall exceed 6 kW; and where two or more heating
units are used, these units shall be so interlocked that not more than 6 kW can be connected at any one
time.

Where electric water heaters not complying with these specifications are installed, the Customer
will be required to pay the original installation or upgrade costs for any nonstandard facilities needed to
supply the electrical capacity to meet the water heater demand. Water heating equipment must not
impair or interfere with service to any other customer.

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of two kW or
larger shall be controlled by approved thermostatic devices. When a group of heating units, with a total
capacity of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so
designed that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-
type heaters, that may be used with a heat exchanger, shall comply with the specifications listed above
for such units.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season

On-Peak: 17:00 p.m. to 911:00 pm. Monday through FridaySaturday, except holidays
Mid-Peak 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays
Off-Peak: 911:00 p.m. to 31:00 p.m. Monday through Friday Saturday and all hours on
weekends Sunday and holidays

Non-summer Season

Idaho Power Company Third RevisedOriginal Sheet No. 5-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 5-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– January 19, 2012Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory
Affairs
Effective – March 1, 2012January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 12-02

On-Peak: 76:00 a.m. to 9:00 pa.m. and 5:00 p.m. to 8:00 p.m. Monday through
FridaySaturday, except holidays
Off-Peak: 9:00 pa.m. to 75:00 ap.m. and 8:00 p.m. to 976:00 a.m. Monday through Friday
Saturday and all hours on weekends Sunday and holidays

Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence
Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November),
and Christmas Day (December 25). When New Year’s Day, Independence Day, or Christmas Day falls
on Sunday, the Monday immediately following that Sunday will be considered a holiday.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $5.0010.00 $5.0010.00

Energy Charge, per kWh
On-Peak 12.891024.6472¢
9.515912.7787¢
Mid-Peak 12.3238¢ n/a
Off-Peak 7.38996.1618¢ 7.38998.5191¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 5-32
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixteenth Third Revised Sheet No. 5-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-DAY PILOTUSE PLAN
(OPTIONAL)
(Continued)

TIME PERIODS (Continued)

[Intentionally Left Blank]Holidays are New Year's Day (January 1), Memorial Day (last Monday in May),
Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday
in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas
Day falls on Saturday, the preceding Friday will be designated a holiday. If New Year’s Day,
Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County
Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small
Farm Energy Credit).

Service Charge, per month $5.00

Energy Charge, per kWh

Summer
Peak 12.8910¢
Off-Peak 7.3899¢

Non-summer
Peak 9.5159¢
Off-Peak 7.3899¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.

Idaho Power Company First RevisedOriginal Sheet No. 6-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101OriginalFirst Revised Sheet No. 6-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024
1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Residential Service, On-Site Generation is desired, and where additional
investment by the Company for new transmission, substation or terminal facilities is not necessary to
supply the desired service. This service is available to Customers intending to operate Exporting Systems
to generate electricity to reduce all or part of the monthly energy usage.

Standard rates will be applicable unless a Customer elects time-of-use. Time-of-use is an
optional, voluntary service that provides Customers the option to take electric service with seasonal time-
of-use energy rates. If a Customer requests to participate in the optional time-of-use service, the
Customer will be placed on time-of-use under this schedule effective with their next billing cycle.

A Customer may terminate their participation in the time-of-use service at any time. However, the
Customer may not subsequently elect time-of-use service under this schedule for one year after the
effective date of cancellation. If a Customer requests to be taken off of time-of-use service under this
schedule, the Customer will be moved back to the default service under this schedule as of the last meter
read date.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate General Service
Schedule will apply. However, if the wiring is so arranged that the service for residential purposes can
be metered separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

4. Customer owns and/or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System.

5. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

Idaho Power Company First RevisedOriginal Sheet No. 6-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101OriginalFirst Revised Sheet No. 6-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024
1221 West Idaho Street, Boise, Idaho
6. Customer meets all applicable requirements detailed in the Company’s Schedule 68,
Interconnections to Customer Distributed Energy Resources.
Idaho Power Company First RevisedOriginal Sheet No. 6-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101OriginalFirst Revised Sheet No. 6-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024
1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

DEFINITIONS

Designated Meter is the retail meter physically connected to the Exporting System.

Idaho Power Company First RevisedOriginal Sheet No. 6-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 6-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

DEFINITIONS (Continued)

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer. A Generation Facility is a DER.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.
Idaho Power Company Original Sheet No. 6-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 6-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc., and the
Company. The installation of the water heating equipment shall conform to all National, State, and
Municipal Codes. No single electric water heating unit shall exceed 6 kW; and where two or more heating
units are used, these units shall be so interlocked that not more than 6 kW can be connected at any one
time.

Where electric water heaters not complying with these specifications are installed, the Customer
will be required to pay the original installation or upgrade costs for any nonstandard facilities needed to
supply the electrical capacity to meet the water heater demand. Water heating equipment must not impair
or interfere with service to any other customer.

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single-phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all national, state, and municipal codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of 2 kW or larger
shall be controlled by approved thermostatic devices. When a group of heating units, with a total capacity
of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so designed
that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-type heaters,
that may be used with a heat exchanger, shall comply with the specifications listed above for such units.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:
Idaho Power Company First RevisedOriginal Sheet No. 6-43
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Original Sheet No. 6-43
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Exporting System; and
Idaho Power Company First RevisedOriginal Sheet No. 6-43
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Original Sheet No. 6-43
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by midnight,
Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net
Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward
to offset consumption at the Designated Meter until they become eligible for transfer on January 1
of the following year.
Idaho Power Company First RevisedOriginal Sheet No. 6-54
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 6-54
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
Idaho Power Company First RevisedOriginal Sheet No. 6-54
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 6-54
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment, as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

Idaho Power Company Sixth RevisedOriginal Sheet No. 6-65
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth First Revised Sheet No. 6-65
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule
is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers
with permanently removed or disabled systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of each
year.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season

On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and
holidays

Non-summer Season

On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through Saturday,
except holidays
Off-Peak: 9:00 a.m. to 5:00 p.m. and 8:00 p.m. to 6:00 a.m. Monday through Saturday and
all hours on Sunday and holidays

Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence
Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November),
and Christmas Day (December 25). When New Year’s Day, Independence Day, or Christmas Day falls
on Sunday, the Monday immediately following that Sunday will be considered a holiday.

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

MONTHLY CHARGE
Idaho Power Company Sixth RevisedOriginal Sheet No. 6-66
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth Sixth Revised Sheet No. 6-66
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County
Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm
Energy Credit).

The following rate structure and charges are subject to change upon Commission approval:

STANDARD RATES (DEFAULT)
Summer Non-summer

Service Charge, per month $5.0010.00 $5.0010.00

Energy Charge, per kWh
First 800 kWh 8.651810.1082¢ 8.03908.8958¢
801-2000 kWh 10.403312.1546¢ 8.86279.8073¢
All Additional kWh Over 2000 12.358514.4385¢ 9.815410.8615¢

TIME-OF-USE RATES (OPTIONAL)

Summer Non-summer

Service Charge, per month $10.00 $10.00

Energy Charge, per kWh
On-Peak 24.6472¢ 12.7787¢
Mid-Peak 12.3238¢ n/a
Off-Peak 6.1618¢ 8.5191¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 7-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 7-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 7
SMALL GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served, and additional investment by the Company for transmission,
substation, or terminal facilities is not necessary to supply the desired service.

APPLICABILITY

Service under this schedule is applicable to Electric Service supplied to a Customer at one Point
of Delivery and measured through one meter. This schedule is applicable to Customers whose metered
energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most
recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under
this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an
actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible
for service under this schedule and will be automatically transferred to the applicable schedule effective
with the next Billing Period. New customers may initially be placed on this schedule based on estimated
usage.

This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo
grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not
applicable to standby service, service for resale, shared service, to individual or multiple family dwellings
first served through one meter after February 9, 1982, or to agricultural irrigation service after October
31, 2004.

TYPE OF SERVICE

The type of service provided under this schedule is single and/or three-phase, at approximately
60 cycles and at the standard service voltage available at the Premises to be served.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August September 301 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of
each year.

Idaho Power Company Seventeenth RevisedOriginal Sheet No. 7-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 7-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 7
SMALL GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine
County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and
Small Farm Energy Credit).

Summer Non-summer

Service Charge, per month $525.00 $525.00

Energy Charge, per kWh
First 300 kWh 9.86336.7404¢ 9.86336.7404¢
All Additional kWh 11.74727.7027¢ 10.34866.7421¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Second RevisedOriginal Sheet No. 8-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 8-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Small General Service, On-Site Generation is desired, and where
additional investment by the Company for new transmission, substation or terminal facilities is not
necessary to supply the desired service. This service is available to Customers intending to operate
Exporting Systems under this schedule to generate electricity to reduce all or part of their monthly energy
usage.

APPLICABILITY

Effective until a final order is issued that addresses metering configuration for Schedule
84 customers, and any appeal period has passed or the order has been upheld on appeal, existing
Schedule 8 customers who no longer meet the energy usage requirement of Schedule 8 that
‘energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the
most recent 12 consecutive Billing Periods[,]’ can elect Schedule 8.

Service under this schedule is applicable to Electric Service supplied to a Customer at one Point
of Delivery and measured through one meter. This schedule is applicable to Customers whose metered
energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most
recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under
this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an
actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible
for service under this schedule and will be automatically transferred to the applicable schedule effective
with the next Billing Period. New customers may initially be placed on this schedule based on estimated
usage.

This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo
grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not
applicable to standby service, service for resale, shared service, to individual or multiple family dwellings
first served through one meter after February 9, 1982, or to agricultural irrigation service after October
31, 2004.

Service under this schedule is also subject to the following conditions:

1. Customer owns/and or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System.

2. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

3. Customer meets all applicable requirements detailed in the Company’s Schedule 68,
Interconnections to Customer Distributed Energy Resources.
Idaho Power Company First RevisedOriginal Sheet No. 8-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 8-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

DEFINITIONS

Designated Meter is the retail meter physically connected to the Exporting System.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electricity energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is either delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer. A Generation Facility is a DER.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods, and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

TYPE OF SERVICE

The type of service provided under this schedule is single and/or three-phase alternating current,
at approximately 60 cycles and at the standard service voltage available at the Premises to be served.

Idaho Power Company First RevisedOriginal Sheet No. 8-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 8-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

Idaho Power Company First RevisedOriginal Sheet No. 8-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 8-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Exporting System; and

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by midnight,
Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net
Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward
to offset consumption at the Designated Meter until they become eligible for transfer on January 1
of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt, or reduce deliveries of energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
Idaho Power Company Sixth RevisedOriginal Sheet No. 8-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth Sixth Revised Sheet No. 8-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule
is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers
with permanently removed or disabled systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of each
year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County
Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm
Energy Credit).

The following charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $5.0025.00 $5.0025.00

Energy Charge, per kWh
First 300 kWh 9.86336.7404¢ 9.86336.7404¢
All Additional kWh 11.74727.7027¢ 10.34866.7421¢

PAYMENT

Idaho Power Company Sixth RevisedOriginal Sheet No. 8-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth Sixth Revised Sheet No. 8-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company First RevisedOriginal Sheet No. 9-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No.9-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30722 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2009 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the Premises to be served and additional investment by the Company for new transmission,
substation, or terminal facilities is not necessary to supply the desired service.

Standard rates will be applicable for Secondary Service unless a Customer elects time-of-use.
Time-of-use is an optional, voluntary service for secondary service that provides secondary service
Customers the option to take electric service with seasonal time-of-use energy rates. If a Customer
requests to participate in the optional time-of-use service, the Customer will be placed on time-of-use
under this schedule effective with their next billing cycle.

A Secondary Service Customer may terminate their participation in the time-of-use service at any
time. However, the Customer may not subsequently elect time-of-use service under this schedule for one
year after the effective date of cancellation. If a Customer requests to be taken off of time-of-use service
under this schedule, the Customer will be moved back to the default service under this schedule as of
the last meter read date.

APPLICABILITY

Service under this schedule is applicable to firm Electric Service supplied to a Customer at one
Point of Delivery and measured through one meter. This schedule is applicable to Customers whose
metered energy usage exceeds 2,000 kWh per Billing Period for a minimum of three Billing Periods during
the most recent 12 consecutive Billing Periods and whose metered Demand per Billing Period has not
equaled or exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods.
This schedule will remain applicable until the Customer’s metered Demand per Billing Period has
exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods. Where the
Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be
prorated to 30 days for purposes of determining eligibility under this schedule. Customers who do not
meet the eligibility requirements for continued service under this schedule will be automatically
transferred to the applicable schedule effective with the next Billing Period. New customers may initially
be placed on this schedule based on estimated usage.

This schedule is not applicable to standby service, service for resale, shared service, to individual
or multiple family dwellings first served through one meter after February 9, 1982, or to agricultural
irrigation service after October 31, 2004.

TYPE OF SERVICE

The type of service provided under this schedule is single-and/or three-phase, at approximately
60 cycles and at the standard service voltage available at the Premises to be served.
Idaho Power Company First RevisedOriginal Sheet No. 9-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No.9-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30722 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2009 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest non-zero monthly Billing Demands
established during the 12-month period which includes and ends with the current Billing Period.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.
Idaho Power Company Third Revised Original Sheet No. 9-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No.9-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32426 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2012 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 17:00 p.m. to 911:00 p.m. Monday through FridaySaturday, except
holidays
Mid-Peak: 73:00 ap.m. to 17:00 p.m. and 911:00 p.m. to 112:00 pa.m. Monday
through FridaySaturdays, , and 7:00 a.m. to 11:00 p.m. Saturday and
Sunday, except holidays
Off-Peak: 112:00 pa.m. to 73:00 ap.m. Monday through Sunday Saturday and all
hours on Sunday and holidays

Non-summer Season
On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 79:00 a.m. to 1112:00 pp.m., 4:00 p.m. to 5:00 p.m.,
and 8:00 p.m. to 10:00 p.m. Monday through Saturday, except holidays
Off-Peak: 112:00 pa.m. to 76:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to
12:00 a.m. Monday through Saturday and all hours on Sunday and
holidays

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.
Idaho Power Company Third Revised Original Sheet No. 9-23
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No.9-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32426 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2012 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned,
operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge
to the Company. This service is provided under the provisions set forth in Rule M, Facilities Charge
Service.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

SUMMER AND NON-SUMMER SEASONS

The summer season beings on June 1 of each year and ends on August September 310 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of
each year.

Idaho Power Company Fourteenth RevisedOriginal Sheet No. 9-34
Cancels
I.P.U.C. No. 2930, Tariff No. 101Thirteenth Fourteenth Revised Sheet No. 9-34
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the
Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit).

SECONDARY SERVICE – STANDARD RATES
SSummer Non-summer
(DEFAULT)

Service Charge, per month $1625.00
$2516.00

Basic Charge, per kW of Basic Load Capacity
Basic Load CapacityFirst 20 kW $0.001.48
$0.001.48
All Additional kW $1.03

Demand Charge, per kW of Billing Demand
First 20 kWBilling Demand $0.007.66
$0.006.04
All Additional kW $6.06 $4.45

Energy Charge, per kWh
First 2,000 All kWh 10.52505.1548¢
9.47424.9718¢
All Additional kWh 4.8716¢ 4.4196¢

SECONDARY SERVICE – TIME-OF-USE (Optional Time-of-Use) Summer
Non-summer
(OPTIONAL)

Service Charge, per month $25.00 $25.00

Basic Charge, per kW of Basic Load Capacity
Basic Load Capacity $1.48 $1.48

Demand Charge, per kW of Billing Demand
Billing Demand $7.66 $6.04

Energy Charge, per kWh
On-Peak 5.5149¢ 5.2572¢
Mid-Peak 5.5149¢ 5.0218¢
Idaho Power Company Fourteenth RevisedOriginal Sheet No. 9-34
Cancels
I.P.U.C. No. 2930, Tariff No. 101Thirteenth Fourteenth Revised Sheet No. 9-34
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Off-Peak 4.9700¢ 4.8345¢

Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 9-45
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 9-45
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $285340.00 $285340.00

Basic Charge, per kW of
Basic Load Capacity $1.301.73 $1.301.73

Demand Charge, per kW of
Billing Demand $5.167.89 $4.527.48

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.971.49 n/a

Energy Charge, per kWh
On-Peak 4.945545.0975¢ n/a4.6295¢
Mid-Peak 4.56335.0975¢
4.09204.4020¢
Off-Peak 4.31334.5704¢
3.95464.2196¢

.
TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $285340.00 $285340.00

Basic Charge, per kW of
Basic Load Capacity $0.691.03 $0.691.03

Demand Charge, per kW of
Billing Demand $4.84 6.95 $4.366.09

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.971.49 n/a

Energy Charge, per kWh
On-Peak 4.86645.0239¢ n/a4.5313¢
Mid-Peak 4.50005.0239¢
4.04084.3036¢
Off-Peak 4.25854.4908¢
3.91554.1210¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 15-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 15-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 15
DUSK TO DAWN CUSTOMER
LIGHTING

AVAILABILITY

Service under this schedule is available to commercial institutions, industrial plants and
residential Customers presently served from the Company’s interconnected system within the State of
Idaho, where existing overhead secondary distribution facilities of adequate capacity, phase and
voltage are presently available adjacent to the Premises to be lighted.

APPLICABILITY

Service under this schedule is applicable to Electric Service provided for the outdoor dusk to
dawn lighting of commercial, industrial and residential Customer grounds, yards, driveways and
Premises by means of a Company-owned luminary mounted on an existing Company pole with a
support bracket and automatically controlled by a photoelectric relay. At the request of a Customer, but
at the sole discretion of the Company, a luminary may be mounted on a Customer-owned support
acceptable to the Company. The type and kind of fixtures and supports will be in accordance with the
Company’s specifications.

CHARACTER OF SERVICE

The facilities required for supplying service, including the lighting fixture, lamp, control relay and
support bracket for mounting on an existing Company pole with secondary service or, at the request of
a Customer and at the Company’s sole discretion, on a Customer-owned support acceptable to the
Company, are supplied, installed, owned and maintained by the Company in accordance with the
Company's standards and specifications. All necessary repairs and maintenance work, including
fixture replacement lamp renewal, will be performed by the Company only during the regularly
scheduled working hours of the Company, and the Company shall be allowed 72 hours following
notification by the Customer for replacing any burned out lighting fixtureslamps. Lighting fixturesLamps
are energized each night from 20 minutes after sunset until 20 minutes before sunrise, thereby
providing approximately 4,059 hours of Premises lighting per year. The Company retains the right, but
not the obligation, to terminate and remove service from a Customer-owned support at any time.

If the Customer requests that the Company install a Company-owned lighting fixtureluminary on
a Customer-owned support, the Customer, through its request, agrees to permit the Company and its
representatives reasonable access onto and across the Customer’s property for the purposes of
installing, maintaining and removing the lighting fixtureluminary. In addition, the Customer voluntarily
agrees to release the Company (including its directors, officers, employees, agents, parent company,
affiliates, successors and assigns) from all liability, loss, claims or actions for injury, death, expenses
(including, but not limited to, reasonable attorney fees and court costs) or damage to person or property
resulting from the Company’s installation, maintenance and removal of the lighting fixture luminary
located on a Customer-owned support. The Customer also agrees to indemnify and hold harmless the
Company from any liability, claim, loss, action or expense (including, but not limited to, reasonable
attorney fees and court costs) asserted against or incurred by the Company for damages arising out of
actions or inactions of the Customer and the Customer’s employees, agents, representatives or others
acting on their behalf.

Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 15-2
Cancels
I.P.U.C. No. 3029, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 15-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 15
DUSK TO DAWN CUSTOMER
LIGHTING
(Continued)

NEW FACILITIES

Where facilities of the Company are not presently available for a lighting fixturelamp installation
which will provide satisfactory lighting service for the Customer's Premises, the Company may install
overhead or underground secondary service facilities, including secondary conductor, poles, anchors,
etc., a distance not to exceed 300 feet to supply the desired service, all in accordance with the charges
specified below.

MONTHLY CHARGE

Effective October 1, 2019, High Pressure Sodium Vapor lighting systems are not available for
new installation.

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

1. Monthly Per Unit Charge on existing facilities:
AREA LIGHTING
High Pressure Sodium Vapor
LED Equivalent Base Rate
Watts Average Lumens Watt (Maximum) Lumen (Minimum)
100 8,550 40 3,600 $ 9.63
200 19,800 85 7,200 $11.50
400 45,000 200 18,000 $15.57
FLOOD LIGHTING
High Pressure Sodium Vapor LED Equivalent Base Rate
Watts Average Lumens Watt (Maximum) Lumen (Minimum)
200 19,800 85 8,100 $13.78
400 45,000 150 18,000 $16.24
Metal Halide LED Equivalent Base Rate
Watts Average Lumens Watt (Maximum) Lumen (Minimum)
400 28,800 150 18,000 $14.91
1,000 88,000 300 32,000 $23.71LED Fixture

Watt (Maximum) Lumen (Minimum) Base Rate
40 3,600 $ 9.45
85 7,200 $11.50
200 18,000 $16.61
FLOOD LIGHTING
LED Fixture
Watt (Maximum) Lumen (Minimum) Base Rate
85 8,100 $18.76
150 18,000 $20.67
300 32,000 $24.31

Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 15-2
Cancels
I.P.U.C. No. 3029, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 15-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

2. For New Facilities Installed Before June 1, 2004: The Monthly Charge for New Facilities
installed prior to June 1, 2004, will continue to be assessed a monthly facilities charge in accordance
with the changes specified in Schedule 66.

3. For New Facilities Installed On or After June 1, 2004: The non-refundable charge for
New Facilities to be installed, such as underground service, overhead secondary conductor, poles,
anchors, etc., shall be equal to the work order cost.

PAYMENT

The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
Idaho Power Company First RevisedOriginal Sheet No. 19-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 19-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32132Gregory W. SaidTimothy E. Tatum, General ManagerVice President,
Regulatory Affairs
Effective – January 1, 2011 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service, those facilities
provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that
additional facilities not provided for under Rule H, including transmission and/or substation facilities, are
required to provide the requested service, special arrangements will be made in a separate agreement
between the Customer and the Company.

APPLICABILITY

Service under this schedule is applicable to and mandatory for Customers who register a metered
Demand of 1,000 kW or more per Billing Period for three or more Billing Periods during the most recent
12 consecutive Billing Periods. Customers whose initial usage, based on information provided by the
Customer, is expected to be 1,000 kW or more per Billing Period for three or more Billing Periods during
12 consecutive Billing Periods may, at the Customer’s request, take service under this schedule prior to
meeting the metered Demand criterion. This schedule will remain applicable until the Customer fails to
register a metered demand of 1,000 kW or more per Billing Period for three or more Billing Periods during
the most recent 12 consecutive Billing Periods.

Deliveries at more than one Point of Delivery or more than one voltage will be separately metered
and billed. If the aggregate power requirement of a Customer who receives service at one or more Points
of Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this
schedule and is required to make special contract arrangements with the Company.

This schedule is not applicable to service for resale, to shared or irrigation service, to standby or
supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or
other standby agreement with the Company, or to multi-family dwellings.

Contract Option. Customers for which this schedule is applicable may optionally take service
under a mutually agreed upon individual special contract between the Customer and the Company
provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special
contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without
change or condition.

TYPE OF SERVICE

The Type of Service provided under this schedule is three-phase at approximately 60 cycles and
at the standard service voltage available at the Premises to be served.

Idaho Power Company Original Sheet No. 19-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 19-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 17:00 p.m. to 911:00 p.m. Monday through FridaySaturday, except
holidays
Mid-Peak: 7:003:00 p.m. a.m. to 17:00 p.m. and 911:00 p.m. to 112:00 pa.m. Monday
through FridaySaturday, and 7:00 a.m. to 11:00 p.m. Saturday and Sunday,
except holidays
Off-Peak: 112:00 pa.m. to 73:00 ap.m. Monday through Sunday Saturday and all
hours on Sunday and holidays

Non-summer Season
On-Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m.
Monday through Saturday, except holidays
Mid-Peak: 79:00 a.m. to 112:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00
p.m. Monday through Saturday, except holidays
Off-Peak: 112:00 pa.m. to 76:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to
12:00 a.m. Monday through Saturday and all hours on Sunday and
holidays

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.

SUMMER AND NON-SUMMER SEASONS

Idaho Power Company Original Sheet No. 19-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 19-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008 January 1, 2024 1221 West Idaho Street, Boise, Idaho
The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of
each year.

Idaho Power Company Thirteenth RevisedOriginal Sheet No. 19-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Twelfth Thirteenth Revised Sheet No. 19-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned,
operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge
to the Company. This service is provided under the provisions set forth in Rule M, Facilities Charge
Service.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

TEMPORARY SUSPENSION

When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic
Load Capacity, the Billing Demand, and the On-Peak Billing Demand shall be prorated based on the
period of such suspension in accordance with Rule G. In the event the Customer's metered demand is
less than 1,000 kW during the period of such suspension, the Basic Load Capacity and Billing Demand
will be set equal to 1,000 kW for purposes of determining the Customer's Monthly Charge.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), and Schedule 96 (Blaine County Surcharge to Fund the
Undergrounding of Certain Facilities).

SECONDARY SERVICE Summer Non-summer

Service Charge, per month $39.0085.00 $39.0085.00

Basic Charge, per kW of
Basic Load Capacity $0.931.90 $0.931.90

Demand Charge, per kW of
Billing Demand $5.999.90 $4.307.97

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $1.03 1.71 n/a

Energy Charge, per kWh
On-Peak 6.44565.6450¢ n/a5.1110
Mid-Peak 5.10345.6450¢
4.74664.8829¢
Idaho Power Company Thirteenth RevisedOriginal Sheet No. 19-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Twelfth Thirteenth Revised Sheet No. 19-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Off-Peak 4.52925.1197¢
4.21714.7000¢
Idaho Power Company Sixteenth RevisedOriginal Sheet No. 19-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifteenth Sixteenth Revised Sheet No. 19-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

MONTHLY CHARGE (Continued)

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $299.00415.00
$299.00415.00

Basic Charge, per kW of $1.282.09 $1.282.09
Basic Load Capacity

Demand Charge, per kW of $6.129.47 $4.548.14
Billing Demand

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.971.50 n/a

Energy Charge, per kWh
On-Peak 5.30494.9253¢ n/a4.4526¢
Mid-Peak 4.21854.9253¢
3.97654.2244¢
Off-Peak 3.76394.3995¢
3.55504.0414¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $299.00415.00
$299.00415.00

Basic Charge, per kW of
Basic Load Capacity $0.711.76 $0.711.76

Demand Charge, per kW of
Billing Demand $5.93 9.61 $4.418.27

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.97 1.50 n/a

Energy Charge, per kWh
On-Peak 5.24474.9086¢ n/a4.4239¢
Mid-Peak 4.18894.9086¢
3.95774.1956¢
Off-Peak 3.73944.3799¢
3.53834.0125¢

PAYMENT

Idaho Power Company Sixteenth RevisedOriginal Sheet No. 19-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifteenth Sixteenth Revised Sheet No. 19-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho
The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
Idaho Power Company Original Sheet No. 19-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 19-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32982 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 25, 2014 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST

Definitions
Additional Schedule 19 Applicant is a Schedule 19 Customer whose Application requires the
Company to provide new or relocated service from Substation Facilities served by an existing section of
Transmission Facilities with a Transmission Vested Interest.

Applicant is a Schedule 19 Customer whose Application requires the Company to provide new or
relocated service from Substation Facilities served by Transmission Facilities that are free and clear of
any Transmission Vested Interest.

Application is a request by an Applicant or Additional Schedule 19 Applicant for new electric
service from the Company.

Connected Load is the total nameplate MW rating of the electric loads connected for Schedule 19
service.

Distribution Facilities include structures, wires, insulators, and related equipment that are
operated at a 34.5 kilovolt or lower rating.

Substation Allowance is the portion of the cost of the Substation Facilities funded by the Company.

Substation Facilities include those facilities and related equipment that transform the voltage of
energy from a 44 kilovolt or higher rating to a 34.5 kilovolt or lower rating.

Transmission Facilities include structures, wires, insulators, and related equipment that are
operated at a 44 kilovolt or higher rating.

Transmission Line Installation is any installation of new Transmission Facilities owned by the
Company.

Transmission Line Installation Charge is the partially refundable charge assessed an Applicant or
Additional Schedule 19 Applicant whenever a Transmission Line Installation is built for that individual.

Transmission Vested Interest is the right to a refund that an Applicant or Additional Schedule 19
Applicant holds in a specific section of Transmission Facilities when Additional Schedule 19 Applicants
attach to that section of Transmission Facilities.

Transmission Vested Interest Charge is an amount collected from an Additional Schedule 19
Applicant for refund to a Transmission Vested Interest Holder.

Transmission Vested Interest Holder is a person or entity that has paid a refundable Transmission
Line Installation Charge to the Company for a Transmission Line Installation.
Idaho Power Company Ninth RevisedOriginal Sheet No. 19-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Eighth Ninth Revised Sheet No. 19-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 1, 2023 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 22-05

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST (Continued)

Definitions (Continued)
Transmission Vested Interest Portion is that part of the Company’s transmission system in which
a Transmission Vested Interest is held.

Substation Allowance

If a Schedule 19 Customer’s request for service requires the installation of new or upgraded
transformer capacity in Substation Facilities, the following considerations will be included in the separate
agreement between the Customer and the Company:

The Customer will initially pay for the cost of new or upgraded Substation Facilities
required because of the Customer’s request. The Customer will be eligible to receive a one-time
Substation Allowance based upon subsequent sustained usage of capacity by the Customer.

a. Substation Allowance: The maximum possible allowance will be
determined by multiplying the Customer’s actual increase in load by $79,444 per MW, but
will not exceed the actual cost of the Substation Facilities.

b. Substation Allowance Refunds: The Substation Allowance will be refunded
to the Customer over a five-year period, with annual payments based on the Customer’s
Basic Load Capacity at the time of refund. The first refund will be paid one year following
the first month energy is delivered through the new Substation Facilities.

The refunds will occur based on the following adjustment, which will be
added to the Substation Allowance received in the previous year. If there is no
change in load from the previous year, the Substation Allowance for that year is
equal to the Substation Allowance from the previous year:

((Change in load from the previous year as measured in MW) x (Substation Allowance per MW))
Number of Substation Allowance Refunds remaining in five-year period

The Customer’s annual refunds will be made in accordance with the
Substation Allowance amount stated in the separate construction agreement
between the Customer and the Company.

Transmission Vested Interest

If a Schedule 19 Customer’s request for service requires the installation of new or upgraded
capacity in Transmission Facilities, and those Transmission Facilities are serving the Customer by a
radial feed, the following considerations will be included in the separate agreement between the
Customer and the Company:
Idaho Power Company Original Sheet No. 19-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 19-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32982 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – February 25, 2014 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 19
LARGE POWER SERVICE
(Continued)

SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST (Continued)

Transmission Vested Interest (Continued)

The Customer will initially pay for the cost of new or upgraded Transmission Facilities required
because of the Customer’s request. The Customer may be eligible to receive Transmission Vested
Interest Refunds in accordance with Schedule 19.

Transmission Vested Interest Refunds.
Transmission Vested Interest Refunds will be paid by the Company and funded by the
Additional Schedule 19 Applicant's Transmission Vested Interest Charge as calculated in
accordance with Schedule 19. The initial Applicant will be eligible to receive refunds up to 80
percent of their original construction cost.

Transmission Vested Interest Refund Limitations
a. Transmission Vested Interest Refunds will be funded by no more than 4 Additional
Schedule 19 Applicants during the 5-year period following the completion date of
the Transmission Line Installation.
b. In no circumstance will refunds exceed 100 percent of the refundable portion of
any party's cash payment to the Company.

Transmission Vested Interest Charges:
Additional Schedule 19 Applicants with a Connected Load of greater than 1 MW who
connect to a Transmission Vested Interest Portion of a Transmission Line Installation will pay a
Transmission Vested Interest Charge to be refunded to the Transmission Vested Interest Holder.

An Additional Schedule 19 Applicant will pay an amount determined by this equation:

Transmission Vested Interest Charge = A x B where;

A = Load Ratio: Additional Schedule 19 Applicant’s Connected Load divided by the sum
of Additional Applicant’s Connected Load and Transmission Vested Interest Holder’s
load.
B = Vested Interest Holder’s un-refunded contribution

The Additional Schedule 19 Applicant has no Transmission Vested Interest and the
Transmission Vested Interest Holder remains the Transmission Vested Interest Holder. The
Transmission Vested Interest Holder’s Transmission Vested Interest will be reduced by the
newest Additional Schedule 19 Applicant’s payment.

The Transmission Vested Interest Charge will not exceed the sum of the Transmission Vested
Interests in the Transmission Line Installation. If an Additional Schedule 19 Applicant connects to a
portion of a vested Transmission Line Installation which was established under a prior rule or schedule,
the Transmission Vested Interest Charges of the previous rule or schedule apply to the Additional
Schedule 19 Applicant.
Idaho Power Company Original Sheet No. 20-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
available. If additional distribution facilities are required to supply the desired service, those facilities
provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that
additional facilities not provided for under Rule H, including transmission and/or substation facilities, are
required to provide the requested service, special arrangements will be made in a separate agreement
between the Customer and the Company.

APPLICABILITY

Service under this schedule is applicable to electric service supplied to a Customer at one Point
of Delivery and measured through one meter delivered at the primary or transmission service level. This
schedule is applicable to Customers whose metered energy usage exceeds 2,000 kWh per Billing Period
for a minimum of three Billing Periods during the most recent 12 consecutive Billing Periods. Where the
Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be
prorated to 30 days for purposes of determining eligibility under this schedule.

Applicable Speculative High-Density Load Large Power Service Rates are mandatory for
Customers who register a metered Demand of 1,000 kW or more per Billing Period for three or more
Billing Periods during the most recent 12 consecutive Billing Periods.

Customers whose metered Demand per Billing Period has not equaled or exceeded 1,000 kW
more than twice during the most recent 12 consecutive Billing Periods will take service under applicable
Speculative High-Density Load Large General Service rates.

At their expense, Customers may request to establish an additional circuit for building systems
independent of the commercial operational load, such as lighting, climate control, among others, at a
separate Point of Delivery. This additional circuit will be separately metered and billed under the
applicable rate schedule. The Customer will be responsible for the costs associated with installing the
second meter. The Company may refuse to provide service at more than one Point of Delivery at the
same Premises if it is determined by the Company that the additional Point of Delivery cannot be provided
without jeopardizing the safety and reliability of the Company's system or service to the Customer or to
other Customers. Service provided to a Customer at multiple Points of Delivery at the same Premises
will not be interconnected electrically.

This schedule is not applicable to service for resale, to shared or irrigation service, to standby or
supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or
other standby agreement with the Company, or to multi-family dwellings.

Idaho Power Company Original Sheet No. 20-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

APPLICABILITY (Continued)

Service under this schedule is applicable to and may be mandatory for Customers who have the
ability to relocate quickly in response to short-term economic signals and meet four or more of the
following criteria:
 High energy use density;
 High load factor;
 Load that is portable and distributable;
 Highly variable load growth or load reduction as an individual customer and/or in aggregate with
similar customers in the Company’s service area;
 High sensitivity to volatile commodity or asset prices;
 Part of an industry with potential to quickly become a large concentration of power demand;
 Lack of credit history or ability to demonstrate financial viability.

If the aggregate power requirement of a Customer who receives service at one or more Points of
Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this
schedule and is required to make special contract arrangements with the Company.

Contract Option. Customers for which this schedule is applicable may optionally take service
under a mutually agreed upon individual special contract between the Customer and the Company
provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special
contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without
change or condition.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Interconnection Facilities are all facilities which are reasonably required by good practices and
the National Electric Safety Code to interconnect the Customer with the capability to remotely interrupt
the load at the Point of Delivery. Such improvements include, but are not limited to, reclosers, load control
devices, and related equipment.

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer with the
capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not
limited to, additional or larger conductors, transformers, poles, and related equipment.

Idaho Power Company Original Sheet No. 20-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

INTERCONNECTION PROCESS

Once a request for new Schedule 20 service is received, Idaho Power will perform a study or
studies to determine what Protection Equipment, Interconnection Facilities, and/or Upgrades are
necessary to interconnect the Customer’s load to Idaho Power’s system. The customer shall pay the
actual costs of all required interconnection studies. Any difference between the deposit (if required) and
the actual cost of the study shall be paid by or refunded to the Customer, as appropriate. If, during the
course of preparing a study, the Company incurs costs in excess of the deposit amount, the Company
may require that the deposit amount be replenished in an amount equal to the estimated costs for
completion of the study. If a deposit amount sufficient to pay for completion of the study is not maintained,
the Company may suspend work on the study.

Idaho Power Company Original Sheet No. 20-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

TYPE OF SERVICE

The Type of Service provided under this schedule is three-phase at approximately 60 cycles
and at the standard service voltage available at the Premises to be served.

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW for Large
Power Service.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays
Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through
Saturday, except holidays
Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday
and holidays

Non-summer Season
On-Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through
Saturday, except holidays
Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m.
Monday through Saturday, except holidays
Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00
a.m. Monday through Saturday and all hours on Sunday and holidays
Summer Season
On-Peak: 1:00 p.m. to 9:00 p.m. Monday through Friday, except holidays
Mid-Peak: 7:00 a.m. to 1:00 p.m. and 9:00 p.m. to 11:00 p.m. Monday through Friday,
except holidays, and 7:00 a.m. to 11:00 p.m. Saturday and Sunday, except
holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Sunday and all hours on holidays

Non-summer Season
Mid-Peak: 7:00 a.m. to 11:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Saturday and all hours on Sunday
and holidays

Idaho Power Company Original Sheet No. 20-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho
The holidays observed by the Company are New Year’s Day, Memorial Day, Independence Day,
Labor Day, Thanksgiving Day, and Christmas Day. When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

Idaho Power Company Original Sheet No. 20-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of
each year.

FACILITIES BEYOND THE POINT OF DELIVERY

Pursuant to Rule B, customers taking Primary or Transmission Service are responsible for
providing the transformation of power to the voltage at which it is to be used by the Customer.

INTERRUPTION EVENTS

At its discretion, Idaho Power may call Interruption Events to remotely disconnect electric service
to Customer load under the following parameters:

 June 15 through September 15
 1:00 p.m. to 11:00 p.m. Monday through Friday, excluding Holidays
 Maximum ten (10) hours per interruption event
 Up to 225 hours annually

Customer will be notified of upcoming Interruption Event not less than two (2) hours prior to event
start via phone call, or at the Company’s discretion via an alternative mutually-agreed upon method.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

SPECIAL CONDITIONS

The provisions of Interruption do not apply for any time period that the Company requests a load
reduction during a system emergency or any other time that a Customer’s service is interrupted by events
outside the control of the Company.

TEMPORARY SUSPENSION

When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic
Load Capacity and the Billing Demand Shall be prorated based on the period of such suspension in
accordance with Rule G.
Idaho Power Company First RevisedOriginal Sheet No. 20-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original First Revised Sheet No. 20-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.- November 28, 2022 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 22-03

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise
Fees).

Large General Service Rates

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $285.00340.00
$285.00340.00

Basic Charge, per kW of $1.30 1.73 $1.301.73
Basic Load Capacity

Demand Charge, per kW of $5.418.39 $4.777.98
Billing Demand

Energy Charge, per kWh
On-Peak 6.93858.8770¢ n/a6.4611
Mid-Peak 5.857411.5970¢
4.98818.2028¢
Off-Peak 5.03546.5765¢
4.48276.9063¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $285.00340.00
$285.00340.00

Basic Charge, per kW of
Basic Load Capacity $0.691.03 $0.691.03

Demand Charge, per kW of
Billing Demand $5.097.45 $4.616.59

Energy Charge, per kWh
On-Peak 6.85958.8034¢ n/a6.3629¢
Mid-Peak 5.794111.5234¢
4.93698.1044¢
Off-Peak 4.98066.4969¢
4.44366.8077¢

Idaho Power Company First RevisedOriginal Sheet No. 20-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 20-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35888 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 14, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

MONTHLY CHARGE (Continued)

Large Power Service Rates

PRIMARY SERVICE Summer Non-summer

Service Charge, per month $299.00415.00
$299.00415.00

Basic Charge, per kW of $1.282.09 $1.282.09
Basic Load Capacity

Demand Charge, per kW of $6.36 9.97 $4.788.64
Billing Demand

Energy Charge, per kWh
On-Peak 7.26638.6996¢ n/a6.2790¢
Mid-Peak 5.480911.4196¢
4.84098.0200¢
Off-Peak 4.45436.4004¢
4.05146.7229¢

TRANSMISSION SERVICE Summer Non-summer

Service Charge, per month $299.00415.00
$299.00415.00

Basic Charge, per kW of
Basic Load Capacity $0.711.76 $0.711.76

Demand Charge, per kW of
Billing Demand $6.1710.11 $4.658.77

Energy Charge, per kWh
On-Peak 7.20618.6829¢ n/a6.2503¢
Mid-Peak 5.451311.4029¢
4.82217.9912¢
Off-Peak 4.42986.3808¢
4.03476.6940¢

PAYMENT

The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
Idaho Power Company First RevisedOriginal Sheet No. 20-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 20-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35888 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 14, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original Sheet No. 20-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35888 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 14, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)

INTERRUPTION COMPENSATION

Fixed Capacity Reduction Rate:

Large General Service Rates $0.0734 0333 per kilowatt of reduction per event
hour

Large Power Service Rates $0.0835 0382 per kilowatt of reduction per event
hour

DEFINITIONS

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

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

“Day of” Load Adjustment. The difference between the Original Baseline kW and the actual
metered kW during the hour prior to the Participant receiving notification of an event. Scalar values will
be calculated by dividing the Original Baseline kW for each Interruption Event hour by the Baseline kW
of the hour preceding the event notification time. The scalars are multiplied by the actual event day kW
for the hour preceding the event notification time to create the Adjusted Baseline kW from which load
reduction is measured. The Adjusted Baseline kW for each hour will be capped at 120% of the maximum
kW amount for any hour from the Highest Energy Use Days or the hours during the event day prior to
event notification.

Facility Site(s). All of a Participant’s facility or equipment that is metered from a single service
location that a Participant has taken service under Schedule 20.

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

Interruption Compensation. The Actual kW Reduction for each hour multiplied by the Fixed
Capacity Reduction Rate. Participants are paid based on the average event kilowatt reduction.

Load Control Device. Refers to any technology, device, or system utilized under Schedule 20 to
enable the Company to initiate the Interruption Event.

Interruption Event. Refers to an event where the Company requests or calls for interruption of
specific loads with the use of one or more Load Control Devices.

Idaho Power Company Original Sheet No. 20-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 20-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35888 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 14, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

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

Idaho Power Company Eighth RevisedOriginal Sheet No. 23-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 23
IRRIGATION PEAK REWARDS PROGRAM
(OPTIONAL)

PURPOSE

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

AVAILABILITY

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

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

PROGRAM DESCRIPTION

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

DEFINITIONS

Notification of Program Acceptance. An interested Customer must sign and return to the
Company an Agreement specifying the Metered Service Point(s) to be included in the Program. If a
Customer is selected for participation in the Program, a notification of acceptance into the Program will
Idaho Power Company Eighth RevisedOriginal Sheet No. 23-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Eighth RevisedOriginal Sheet No. 23-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

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

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

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

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

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

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

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

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

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

Demand Credit. The Demand Credit is a demand-based financial incentive provided in the form
of a credit on the monthly bill for the Metered Service Point enrolled in the Program. The monthly Demand
Credit is calculated by multiplying the Program kW by the demand-related incentive amount for the
Interruption Option selected by the Customer. The Demand Credit will be included on the Customer’s
monthly bills for usage that occurs during the calendar months of June, July, August, and September of
each year. This amount may be prorated for the number of days during the months of June, July, August,
and September that fall in the Customer’s billing cycle to correspond with the Program Season.
Demand Credit = Program kW x demand-related incentive amount
Idaho Power Company Eighth RevisedOriginal Sheet No. 23-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

DEFINITIONS (Continued)

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

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

INTERRUPTION OPTIONS

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

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

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

Idaho Power Company Eighth RevisedOriginal Sheet No. 23-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Seventh Eighth Revised Sheet No. 23-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

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

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

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

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

Customers participating in the Manual Dispatch Option are required to provide no
less than their Nominated Demand during each Load Control Event. Each time a customer
chooses to provide less than their Nominated Demand during one of the Load Control Events, an
opt-out fee of $6.25 per kW will be assessed on the Nominated Demand not made available for
interruption. The opt-out fee will not exceed the total Bill Credit for the Program Season. Any
opt-out fee will be applied at the end of the Program Season or after the applicable billing cycle
closes. Opt-out fees may be waived for circumstances involving planned or unplanned outages
of 3 hours or more occurring within 24 hours of a Load Control Event or a multiday outage within
72 hours of an event.
Idaho Power Company Eighth RevisedOriginal Sheet No. 23-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

INTERRUPTION OPTIONS (Continued)

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

INCENTIVE STRUCTURE

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

INSTALLATION FEES

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

TERM OF AGREEMENT AND TERMINATION

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

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

Demand Credit
($ per Program kW)
Energy Credit
($ per Program kWh)
Energy Credit ($
per Program
kWh) for Out-of-
Demand
Season Billing
Cycles
Standard
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
Extended
Interruption
Variable Energy
Credit
($ per Variable
Program kWh)
$5.25 $0.008 $0.021 $0.18 $0.25
Idaho Power Company Eighth RevisedOriginal Sheet No. 23-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

TERM OF AGREEMENT AND TERMINATION (Continued)

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

Termination Fees:

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

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

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

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

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

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

SPECIAL CONDITIONS

The provisions of this schedule do not apply for any time period that the Company utilizes a Load
Control Device installed under this Program to interrupt the Customer’s load for a system emergency in
accordance with NERC standards, Idaho Power’s Rule J, or any other time that a Customer’s service is
interrupted by events outside the control of the Company. The provisions of this schedule will not affect
the calculation or rate of the regular Service, Energy or Demand Charges associated with a Customer’s
standard service schedule.
Idaho Power Company Eighth RevisedOriginal Sheet No. 23-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 23-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement

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

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

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

NOW, THEREFORE, The Parties agree as follows:

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

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

Idaho Power Company Seventh RevisedOriginal Sheet No. 23-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. 23-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

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

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

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

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

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

Idaho Power Company Sixth RevisedOriginal Sheet No. 23-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth Sixth Revised Sheet No. 23-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 30, 2015Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – January 1, 2024 February 15, 2016 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

7. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s ability to
initiate a Load Control Event at a Metered Service Point(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.

8. The Company’s Schedule 23, any revisions to that schedule and/or any successor schedule are
to be considered part of this Agreement.

9. 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 Idaho Public Utilities
Commission and such other administrative bodies having jurisdiction.

10. Nothing herein shall be construed as limiting the Idaho Public Utilities Commission from changing
any terms, rates, charges, classification of service or any rules, regulations or conditions relating
to service under this Agreement, or construed as affecting the right of the Company or the
Customer to unilaterally make application to the Commission for any such change.

11. In 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.

12. The Company retains the sole right to select and reject the participants to receive service under
Schedule 23. The Company retains the sole right for its employees and its representatives to
install or not install Load Control Devices on the Customer’s electrical panel at the time of
installation depending on, but not limited to, safety, reliability, or other issues that may not be in
the best interest of the Company, its employees or its representatives.

Idaho Power Company Sixth RevisedOriginal Sheet No. 23-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifth Sixth Revised Sheet No. 23-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– December 30, 2015Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – January 1, 2024 February 15, 2016 1221 West Idaho Street, Boise, Idaho
Advice No. 15-16

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

Uniform Irrigation Peak Rewards Service
Application/Agreement
(Continued)

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.

14. 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)

Idaho Power Company Second RevisedOriginal Sheet No. 24-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 24-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – December 15, 2011Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – December 31, 2011 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 11-04

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company’s interconnected system within
the State of Idaho for loads up to 20,000 kW where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the Premises to be served, and additional investment by the Company
for new transmission, substation or terminal facilities is not necessary to supply the desired service. If
the aggregate power requirement of a Customer who receives service at one or more Points of Delivery
on the same Premises exceeds 20,000 kW, special contract arrangements will be required.

APPLICABILITY

Service under this schedule is applicable to power and energy supplied to agricultural use
customers operating water pumping or water delivery systems used to irrigate agricultural crops or
pasturage at one Point of Delivery and through one meter. Water pumping or water delivery systems
include, but are not limited to, irrigation pumps, pivots, fertilizer pumps, drainage pumps, linears, and
wheel lines.

TYPE OF SERVICE

The type of service provided under this schedule is single- and/or three-phase, alternating current,
at approximately 60 cycles and at the standard voltage available at the Premises to be served.

DEFINITIONS

Cumulative Past Due Balance. The Cumulative Past Due Balance is calculated as the sum of all
Schedule 24 past due account balances for which the Customer is financially responsible.

New Irrigation Customer. A New Irrigation Customer is a Customer who, within the previous four
years, has not received Schedule 24 service in the Customer’s name or has received Schedule 24 service
in the Customer’s name for less than three full billing cycles during an Irrigation Season.

Irrigation Season. The Irrigation Season will begin with the Customer's meter reading for the May
Billing Period and end with the Customer's meter reading for the September Billing Period. The beginning
cycles of a Billing Period may actually be based on meter readings taken not more than seven days prior
to the start of the corresponding calendar month.

SERVICE CONNECTION AND DISCONNECTION

The Company will routinely keep service connected throughout the calendar year unless the
Customer requests disconnection. Customer requested service disconnections will be made at no
charge during the Company’s normal business hours. The Company’s termination practices as specified
under Rule F will continue to apply with the exception that service terminations will not be made during
the Irrigation Season.

Idaho Power Company Second RevisedOriginal Sheet No. 24-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 24-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32426 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2012 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

SERVICE CONNECTION AND DISCONNECTION (Continued)

Service Connection Charge. A Service Connection Charge as specified in Schedule 66 will be
assessed when service is reconnected.

Service Establishment Charge. A Service Establishment Charge as specified in Schedule 66 will
be assessed when service that is currently energized at the Point of Delivery is established for the
Customer.

Additional Requirements for Connection or Establishment of Service. The Cumulative Past Due
Balance for all of the Customer’s Schedule 24 metered service points must be paid by the Customer
before service will be connected or established. In addition, before service will be provided to a Schedule
24 metered service point, the applicable deposit for that metered service point must be satisfied.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor; PROVIDED That at the Company's
option the Billing Demand of a single motor installation of 5 horsepower and less may be equal to the
number of horsepower but not less than 1 kW. Metered power demands in kW which exceed 130 percent
of the connected horsepower served through one Point of Delivery will not be used for billing purposes
unless and until verified by a field test in the presence of the Customer to be the result of normal pumping
operations. If a demand in excess of 130 percent of the connected horsepower is the result of abnormal
conditions existing on the Company’s interconnected system or the Customer’s system, including
accidental equipment failure or electrical supply interruption which results in the temporary separation of
the Company’s and the Customer’s system, the Billing Demand shall be 130 percent of the connected
horsepower. Customers may appeal the Company’s billing decision to the Commission in cases of
dispute.

FACILITIES BEYOND THE POINT OF DELIVERY

At the Customer’s request and at the option of the Company, transformers and other facilities
installed beyond the Point of Delivery to provide Transmission Service may be owned, operated, and
maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company.
This service is provided under the provisions set forth in Rule M, Facilities Charge Services.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.
Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 24-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 24-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 28, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), Schedule 96 (Blain County Surcharge to Fund the
Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit).

SECONDARY SERVICE In-Season Out-of-Season

Service Charge, per month $22.00 30.00
$3.506.00
Demand Charge, per kW of
Billing Demand $7.0614.06 n/a

Energy Charge
In-Season
First 164 kWh per kW of Demand 5.8436¢ n/a
All Other kWh per kW of Demand 5.5483¢ n/a
Out-of-Season
All kWh n/a5.7265¢
6.70846.7288¢

TRANSMISSION SERVICE In-Season Out-of-Season

Service Charge, per month $299.00415.00
$3.506.00

Demand Charge, per kW of
Billing Demand $6.6613.27 n/a

Energy Charge
In-Season
First 164 kWh per kW of Demand 5.5978¢ n/a
All Other kWh per kW of Demand 5.3233¢ n/a
Out-of-Season
All kWh n/a5.4849¢
6.40326.4215¢

Idaho Power Company First RevisedOriginal Sheet No. 24-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 24-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – December 15, 2011Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – December 31, 2011 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 11-04

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

MONTHLY CHARGE (Continued)

Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Demand Charge, the
Energy Charge, the Power Cost Adjustment, and the Facilities Charge.

PAYMENT

All monthly billings for Electric Service supplied hereunder are payable upon receipt, and become
past due 15 days from the date on which rendered. (For any agency or taxing district which has notified
the Company in writing that it falls within the provisions of Idaho Code § 67–2302, the past due date will
reflect the 60-day payment period provided by Idaho Code § 67–2302.)

Deposit. A deposit payment for Schedule 24 Customers is required under the following
conditions:

1. Existing Customers.

a. Tier 1 Deposit. A Tier 1 Deposit will be required from Customers who have
received two or more reminder notices for nonpayment during the most recent 12-month period
during which service was received, have had service terminated for nonpayment during the last
four years and have not subsequently received Schedule 24 service, or were required to pay a
Tier 2 Deposit for the previous Irrigation Season. A Tier 1 Deposit may be satisfied by a guarantee
of payment from a bank or financial institution acceptable to the Company. A reminder notice is
issued approximately 45 days after the bill issue date if the balance owing for Electric Service
totals $100 or more or approximately 105 days after the bill issue date for Customers meeting the
provisions of Idaho Code § 67–2302. A Customer with at least one Schedule 24 account that
meets the requirements for payment of a Tier 1 Deposit will be required to pay a Tier 1 Deposit
on all Schedule 24 accounts for which the Customer is financially responsible and requesting
Schedule 24 service. A Tier 1 Deposit does not apply to Customers who have a Cumulative Past
Due Balance on December 31 equal to or greater than $1,0500 (See Tier 2 Deposit). The deposit
for each metered service point is computed as follows:

(1) Monthly Billing Demand is determined by multiplying 80 percent times the
connected horsepower.

(2) Monthly Energy (billing kWh) is determined by multiplying 50 percent times
720 hours times the Monthly Billing Demand.

(3) The Monthly Billing Demand and the Monthly Energy are multiplied by the
current In-Season rates and added to the Irrigation In-Season Service Charge to
determine the estimated monthly bill.

(4) The estimated monthly bill is multiplied by a factor of one and one-half (1.5).
Idaho Power Company First RevisedOriginal Sheet No. 24-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 24-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – December 15, 2011Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – December 31, 2011 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 11-04

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

PAYMENT (Continued)

b. Tier 2 Deposit. Customers with a Cumulative Past Due Balance equal to or greater
than $1,0500 on December 31 will be required to pay a Tier 2 Deposit on all Schedule 24 accounts
for which the Customer is financially responsible and requesting Schedule 24 service. A Tier 2
Deposit will also be required from Customers who have had a Cumulative Past Due Balance
equal to or greater than $1,0500 on December 31 during any of the previous four years and who
have not subsequently had active Schedule 24 service. A Tier 2 Deposit may be satisfied by a
guarantee of payment from a bank or financial institution acceptable to the Company. The deposit
for each metered service point is computed as follows:

(1) Monthly Billing Demand is determined by multiplying 80 percent times the
connected horsepower.

(2) Monthly Energy (billing kWh) is determined by multiplying 50 percent times
720 hours times the Monthly Billing Demand.

(3) The Monthly Billing Demand and the Monthly Energy are multiplied by the
current In-Season rates and added to the Irrigation In-Season Service Charge to
determine the estimated monthly bill.

(4) The estimated monthly bill is multiplied by a factor of four (4).

2. New Irrigation Customers. A Tier 1 Deposit will be required from a New Irrigation
Customer unless the New Irrigation Customer had a Cumulative Past Due Balance equal to or greater
than $1,0500 on December 31 during any of the previous four years and has not subsequently had
Schedule 24 service, in which case a Tier 2 Deposit will be required. The deposit for each metered
service point will be computed using the same methodology as outlined for existing Customers requiring
a Tier 1 or Tier 2 Deposit. A Tier 1 or Tier 2 Deposit for New Irrigation Customers may be satisfied by a
guarantee of payment from a bank or financial institution acceptable to the Company.

3. Bankruptcy or Receivership. An adequate assurance of payment as agreed to by the
Company or as ordered by a court of competent jurisdiction or the Commission shall be required from
any Customer for whom an order for relief has been entered under the federal bankruptcy laws, or for
whom a receiver has been appointed in a court proceeding. As a condition of service, an adequate
assurance of payment equal to a Tier 2 Deposit shall be required. This requirement shall continue from
the date of the order for relief in bankruptcy, or the court appointing a receiver, until the dismissal of the
bankruptcy, or the dismissal of the court proceeding, or until the bankruptcy plan has been completed.

A Customer who has been discharged from bankruptcy, a Customer whose receivership
proceeding has been terminated, or a Customer whose bankruptcy proceedings have been dismissed
will be required to pay an amount equal to a Tier 2 Deposit at the start of the Irrigation Season.

Idaho Power Company First RevisedOriginal Sheet No. 24-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 24-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – December 15, 2011Gregory W. SaidTimothy E. Tatum, Vice President,
Regulatory Affairs
Effective – December 31, 2011 January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 11-04

SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)

APPLICATION OF DEPOSIT/INTEREST

Interest will be computed by the Company on irrigation deposits and adequate assurance of
payments required under this schedule at the annual percentage rate determined by the Commission
under Utility Customer Relations Rules 106.02. The irrigation deposit, with accrued interest, will be
applied to the Customer’s account as follows:

Tier 1 Deposits/Interest. All Tier 1 Deposits plus accrued interest will be applied to the
Customer’s account upon date of disconnection or at the time the Customer’s September bill is
prepared, whichever is earlier.

Tier 2 Deposits/Interest. A portion of the Tier 2 Deposit plus accrued interest equal to the
monthly billing amount will be applied to the Customer’s account each month until the Tier 2
Deposit amount plus accrued interest is depleted. Any Tier 2 Deposit amount and/or accrued
interest remaining at the date of service disconnection or at the time of the Customer’s September
billing, whichever is earlier, will be applied to the Customer’s account

Bankruptcy/Interest. Adequate assurance of payments for customers with an active
bankruptcy or court-appointed receivership will be retained by the Company for each active
irrigation account, rather than refunded annually. Prior to each Irrigation Season, the Company
shall request the difference owed to secure an amount equal to a Tier 2 deposit. Any amount and
accrued interest remaining at the date of service disconnection, the date of the order for relief in
bankruptcy, the dismissal date of the bankruptcy, or the dismissal of the court proceeding, will be
refunded or applied to the Customer’s account if a balance exists.

Each irrigation Customer, upon making a deposit payment, will be required to furnish to the
Company an IRS Tax Identification or Social Security number for the Company’s IRS reporting
requirements.

The Company may refuse to accept and retain any deposit that has not been requested or
demanded by the Company. If, however, the Company accepts the deposit that was not requested, the
Company will apply the deposit to the Customer’s account and no interest will be paid.

LATE PAYMENT CHARGE

A Late Payment Charge will be assessed Customers receiving service under this schedule as
provided under Rule G.

Idaho Power Company Sixteenth RevisedOriginal Sheet No. 26-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifteenth Sixteenth Revised Sheet No. 26-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35735 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO

SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED MAY 31, 2023

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees). Terms used below have the meanings given to them in the
Special Contract referenced above.

Monthly Contract Demand Charge
$1.673.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$10.9816.60 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 25,000 kilowatts.

Daily Excess Demand Charge
$0.2911.244 per each kW over the Contract Demand.

Monthly Energy Charge
2.81503.0394¢ per kWh of Supplemental Energy.

Embedded Energy Fixed Cost Charge
0.26320000¢ per kWh of Renewable Resource On-Site Usage

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos.1, 2, 3, and Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022,
as amended.

Renewable Resource Cost
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022, as amended.

Excess Generation Credit
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated March 9, 2022, as amended.

Administrative Charge
As defined in Revised Exhibit 1 of Micron’s Special Contract, dated Month March 9, 2022, as
amended.

Idaho Power Company Original Sheet No. 26-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 26-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35735 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO

SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED MAY 31, 2023
(Continued)

RENEWABLE RESOURCE AGREEMENTS

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the tables
below. The Monthly Adjusted Renewable Capacity Credit will be provided to Micron monthly, starting the
month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in Table 3) or the month
following the respective Project’s commercial operation date, whichever is later, and will remain in effect for
the duration of the term of the Renewable Resource PPA or the period of time during which the Idaho
Power-owned Renewable Resource will provide Project Output to Micron, as applicable. The Monthly
Adjusted Renewable Capacity Credit will be provided in accordance with Revised Exhibit 1 of Micron’s
Special Contract, dated March 9, 2022, as amended.

TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit
Rate
$/kW-r
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Black
Mesa
Energy
LLC
2019 40,000 0.3642 14,568 $121.19 1.0 $1,765,495.91
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Black
Mesa
Energy
LLC1
$92,689 $92,689 $308,962 $617,924 $308,962 $79,447 $79,447 $92,689 $92,689

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date
Black Mesa
Ener LLC
2/16/2022 2026 7/1/2026

1Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-22-06, Attachment 1 to Idaho Power Company’s Compliance Filing dated December 23, 2022, as
approved in Order No. 35735 (Apr. 12, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.

Idaho Power Company Fifteenth RevisedOriginal Sheet No. 29-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenthifteenth Revised Sheet No. 29-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 29
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
J. R. SIMPLOT COMPANY
POCATELLO, IDAHO

SPECIAL CONTRACT DATED JUNE 29, 2004

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Contract Demand Charge
$23.311 per kW of Contract Demand

Demand Charge,
$7.8814.23 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW

Daily Excess Demand Charge
$0.2921.244 per each kW over the Contract Demand

Energy Charge
2.83452.9887¢ per kWh

Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.A Monthly Facilities Charge will be paid for the Company’s investment in
Distribution Facilities. A Monthly Facilities Charge rate of 1.41% will be paid for facilities installed for 31
years or less and a rate of 0.59% will be paid for facilities installed more than 31 years.

Idaho Power CompanySeventeenth RevisedOriginal Sheet No. 30-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixteenth Seventeenth Revised Sheet No. 30-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 30
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE

SPECIAL CONTRACT DATED SEPTEMBER 15, 2021
CONTRACT NO. 47PA0420D0011

AVAILABILITY

This schedule is available for firm retail service of electric power and energy delivered for the
operations of the Department of Energy's facilities located at the Idaho National Engineering Laboratory
site, as provided in the Contract for Electric Service between the parties.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

1. Demand Charge, per kW of
Billing Demand $8.509.75

2. Energy Charge, per kWh 2.97094.0951¢

SPECIAL CONDITIONS

1. Billing Demand. The Billing Demand shall be the average kW supplied during the 30-
minute period of maximum use during the month.

2. Power Factor Adjustment. When the Power Factor is less than 95 percent during the 30-
minute period of maximum load for the month, Company may adjust the measured Demand to determine
the Billing Demand by multiplying the measured kW of Demand by 0.95 and dividing by the actual Power
Factor.

MONTHLY ANTELOPE ASSET CHARGE (“AAC”)

The AAC will be paid for the Company’s investment in, and operation and maintenance expenses
associated with, specified transmission facilities required to provide service under the contract.

The Monthly AAC consists of two components:

1. PacifiCorp Pass-Through Charge (PPTC):

PPTC = (O&M x GAV) + (CEC)

Idaho Power Company First RevisedOriginal Sheet No. 30-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 30-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.35157 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – September 15, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 30
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE

SPECIAL CONTRACT DATED SEPTEMBER 15, 2021
CONTRACT NO. 47PA0420D0011
(Continued)

MONTHLY ANTELOPE ASSET CHARGE (“AAC”) (Continued)

2. Idaho Power Ownership Costs (OC):

OC = (ROC x AV) + (PT x AV) + (ROR x NRBA) + (IT x NRBA)

Table 1: Description of AAC Rate Components

Item Description Source
O&M PacifiCorp Operations & Maintenance Expense PacifiCorp OATT1 Formula Rate
GAV Gross Asset Value AV plus original asset value per JOOA2
CEC PacifiCorp Common Equipment Charge PacifiCorp OATT Formula Rate; JOOA Exhibit D
ROC Recovery of Capital Rate Idaho Power OATT Formula Rate
V Joint-Owned Acquisition Value V per JOOA plus utility costs to replace assets
PT Property Taxes Rate Actual Idaho Power Property Tax Data
ROR Rate of Return Current Idaho Power Retail Rate of Return
NRBA Net Rate Base Amount V less accumulated depreciation and ADIT3
IT Income Taxes Rate Idaho Power OATT Formula Rate

The Monthly AAC will reflect the charges detailed in the formulas above according to the most
current values from the data sources listed in Table 1, to be updated annually on October 1, with the exception
of ROR, which will be updated in accordance with its effective date.

1 Open Access Transmission Tariff
2 Joint Ownership and Operating Agreement
3 Accumulated deferred income taxes

Idaho Power Company Seventh RevisedOriginal Sheet No. 31-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. 31-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32585 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 July 1, 2012 1221 West Idaho Street, Boise, Idaho

SCHEDULE 31
IDAHO POWER COMPANY
AGREEMENT FOR SUPPLY OF
STANDBY ELECTRIC SERVICE
FOR
THE AMALGAMATED SUGAR COMPANY

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Standby Contract Demand Charge, per kW of
Standby Contract Demand $0.553.11

Standby Facilities Contract Demand Charge
Per kW of Standby Facilities Contract Demand:
Paul Facility: $1.693.45
Nampa Facility: $1.713.47
Twin Falls Facility: $1.343.15

Standby Billing Demand Charge, per kW of
Standby Billing Demand $2.751.67

Excess Demand Charge
$0.641.24 per day for each kW taken in excess of the Total Contract Demand. during the
months of September through March

$0.96 per day for each kW taken in excess of the Total Contract Demand during the months of
April through August

$6.41 per kW for the highest Excess Demand recorded during the Billing Period. (This charge
will not be prorated.)

Energy Charge Energy taken with Standby Demand will be priced at the applicable Schedule 19
Energy Charge.

Idaho Power Company Sixth Original Revised Sheet No. 32-1
Cancels
I.P.U.C. No. 29,30, Tariff No. 101 Fifth Sixth Revised Sheet No. 32-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 32
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
J. R. SIMPLOT COMPANY
CALDWELL, IDAHO

SPECIAL CONTRACT DATED APRIL 8, 2015

APPLICABILITY

Service under this schedule is applicable beginning the first day of the month in the first month
that the aggregate power requirement at one or more Points of Delivery at the Simplot Facility located
near or at 16551 Simplot Boulevard, Caldwell, Idaho, exceeds 20,000 kW.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September October 1 of each year and ends on May 31 of
each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-Summer
Contract Demand Charge
per kW of Contract Demand $1.783.11 $1.783.11

Demand Charge
per kW of Billing Demand but no less
than the Contract Demand less 10,000 kW $14.8718.49 $8.6515.28

Daily Excess Demand Charge
per each kW over the Contract Demand $0.2981.244 $0.2981.244

Energy Charge
per kWh 3.12522.8675¢ 3.06643.0975¢

Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.

Idaho Power Company Original Sheet No. 33-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.

SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED AUGUST 3, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor.

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 17:00 p.m. to 911:00 p.m. Monday through FridaySaturday, except
holidays
Mid-Peak: 73:00 ap.m. to 17:00 p.m. and 911:00 p.m. to 112:00 pa.m. Monday
through FridaySaturday, except holidays, and 7:00 a.m. to 11:00 p.m.
Saturday and Sunday, except holidays
Off-Peak: 121:00 pa.m. to 73:00 ap.m. Monday through Sunday Saturday and all
hours on Sunday and holidays

Non-summer Season
On Peak 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m.
Monday through Saturday, except holidays
Mid-Peak: 79:00 a.m. to 112:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00
p.m. Monday through Saturday, except holidays
Idaho Power Company Original Sheet No. 33-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho
Off-Peak: 112:00 pa.m. to 76:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to
12:00 a.m. Monday through Saturday and all hours on Sunday and
holidays
Idaho Power Company Original Sheet No. 33-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

TIME PERIODS (Continued)

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day, Thanksgiving Day (fourth Thursday in
November), and Christmas Day (December 25). When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September 1October 1 of each year and ends on May 31 of
each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $299415.00 $299415.00

Basic Charge, per kW of
Basic Load Capacity $0.711.76 $0.711.76

Demand Charge, per kW of
Billing Demand $5.939.61 $4.418.27

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.971.50 n/a

Energy Charge, per kWh
On-Peak 5.24474.9086¢ n/a4.4239¢
Mid-Peak 4.18894.9086¢
3.95774.1956¢
Off-Peak 3.73944.3799¢
3.53834.0125¢

Embedded Energy Fixed Cost Rate, per kWh
On-Peak 2.43110.6951¢ n/a1.5569¢

Idaho Power Company Original Sheet No. 33-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho
Mid-Peak 1.37530.6951¢
1.14411.5569¢
Off-Peak 0.92580.6951¢
0.72471.5569¢

Idaho Power Company Original Sheet No. 33-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

BLOCK 2

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).
Terms used below have the meanings given to them in the Special Contract referenced above.

Daily Excess Demand Charge
$1.1961.244 per each kW over the Contract Demand.

Excess Generation Credit
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021 as
amended.

Monthly Contract Demand Charge
$2.993.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$10.7521.01 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos. 1, 2, 3, and Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated
December 22, 2021, as amended.

Renewable Resource Cost
As included in the Monthly Contract Payment listed in Revised Exhibit 3.1 of Brisbie, LLC’s Special
Contract, December 22, 2021, as amended.

Supplemental Energy Cost
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Administrative Charge
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Idaho Power Company Original Sheet No. 33-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 33-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

Renewable Resource Agreements

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project’s commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated December 22, 2021, as amended.

TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit Rate
($/kW-yr)
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Pleasant
Valley
Solar
LLC
2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Pleasant
Valley
Solar LLC1
$416,057 $416,057 $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date
Pleasant
Valley
Solar LLC
10/27/2022 2023 6/1/2023

1 Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42, Attachment 1 to Idaho Power Company’s Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.
Idaho Power Company Original Sheet No. 34-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 34-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35929 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - September 21, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.

SPECIAL CONTRACT DATED MAY 5, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor. If a Power Factor
adjustment is necessary, the application of the adjustment will be applied to each respective Block at that
Block’s Billing Demand Charge.

Initial Power Factor Adjustment. Effective with the first month’s billing under Schedule 34, and
effective through May 2024 usage, if a Power Factor adjustment is necessary, the application of the 95
percent adjustment will be applied only to the Block 2 Billing Demand. Block 1 Billing Demand will be
subject to a 90 percent Power Factor adjustment during this period.

Block 1 means the first 20,000 kilowatt of the aggregate power requirement at the Lamb Weston Facility.

Block 2 means the aggregate power requirement at the Lamb Weston Facility exceeding the first 20,000
kilowatt.

Block 1 Pricing means the retail rates as defined in Idaho Power Company’s current Idaho retail tariff
Schedule 19 Large Power Service – Primary Service.

Block 1 Energy is the Block 1 Billing Demand multiplied by the Monthly Load Factor multiplied by the
number of hours in the billing month. Block 1 Energy will be subject to the applicable Block 1 Energy
Charge.

Block 2 Energy is the Block 2 Billing Demand multiplied by the Monthly Load Factor multiplied by the
number of hours in the billing month. Block 2 Energy will be subject to the applicable Block 2 Energy
Charge.

Monthly Load Factor is the total aggregate energy consumption at the Lamb Weston facility for the billing
month divided by the number of hours in the billing month divided by the sum of Block 1 and Block 2
Billing Demand.

Idaho Power Company Original Sheet No. 34-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 34-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35929 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - September 21, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 17:00 p.m. to 911:00 p.m. Monday through FridaySaturday,
except holidays
Mid-Peak: 73:00 ap.m. to 17:00 p.m. and 911:00 p.m. to 112:00 pa.m. Monday
through FridaySaturday, except holidays, and 7:00 a.m. to 11:00 p.m.
Saturday and Sunday, except holidays
Off-Peak: 112:00 pa.m. to 73:00 ap.m. Monday through Sunday Saturday and all
hours on Sunday and holidays

Non-summer Season
On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m.
Monday through Saturday, except holidays
Mid-Peak: 79:00 a.m. to 112:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00
p.m. Monday through Saturday, except holidays
Off-Peak: 112:00 pa.m. to 76:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to
12:00 a.m. Monday through Saturday and all hours on Sunday and holidays

TIME PERIODS (Continued)
Idaho Power Company Original Sheet No. 34-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 34-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35929 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - September 21, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last
Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day
(fourth Thursday in November), and Christmas Day (December 25). When New Year’s Day,
Independence Day, or Christmas Day falls on a Sunday, the Monday immediately following that Sunday
will be considered a holiday.

Idaho Power Company Original Sheet No. 34-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 34-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35929 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - September 21, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31September 30 of each
year. The non-summer season begins on September 1October 1 of each year and ends on May 31 of
each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $299.00415.00
$299.00415.00

Basic Charge, per kW of
Basic Load Capacity $1.282.09 $1.282.09

Demand Charge, per kW of
Billing Demand $6.12 9.47 $4.548.14

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.97 1.50 n/a

Energy Charge, per kWh
On-Peak 5.30494.9253¢ n/a4.4526¢
Mid-Peak 4.21854.9253¢
3.97654.2244¢
Off-Peak 3.76394.3995¢
3.55504.0414¢

Idaho Power Company Original Sheet No. 34-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 34-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35929 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - September 21, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 34
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
LAMB WESTON, INC.
(Continued)

BLOCK 2

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).

Daily Excess Demand Charge
$1.244 per each kW over the Contract Demand.

Monthly Contract Demand Charge
$3.11 per kW of Contract Demand.

Monthly Billing Demand Charge
$14.6222.85 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Energy Charge
$0.05.8694¢ per kWh of Block 2 Energy.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Idaho Power Company Second RevisedOriginal Sheet No. 40-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 40-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32426 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2012 1221 West Idaho Street, Boise, Idaho

SCHEDULE 40
NON-METERED GENERAL SERVICE

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing secondary distribution facilities of adequate capacity, phase and voltage
are available adjacent to the Customer’s Premises and the only investment required by the Company is an
overhead service drop.

APPLICABILITY

Service under this schedule applies to Electric Service for the Customer’s single- or multiple-unit
loads up to 1,800 watts per unit where the size of the load and period of operation are fixed and, as a result,
actual usage can be accurately determined. Service may include, but is not limited to, security lighting,
telephone booths and CATV power supplies which serve line amplifiers. Equipment or loads constructed or
operated in such a way as to allow for the potential or actual variation in energy use are not eligible for
service under this schedule. Facilities to supply service under this schedule shall be installed so that service
cannot be extended to the Customer’s loads served under other schedules. Service under this schedule is
not applicable to shared or temporary service. On or after June 1, 2006, new service under this schedule is
also not applicable to the Customer’s loads on Premises which have metered service.

SPECIAL TERMS AND CONDITIONS

The Customer shall pay for all Company investment, except the overhead service drop, required to
provide service requested by the Customer. The Customer is responsible for installing, owning and
maintaining all equipment, including necessary underground circuitry and related facilities to connect with
the Company's facilities at the Company designated Point of Delivery. If the Customer's equipment is not
properly maintained, service to the specific equipment will be terminated.

Energy used by CATV power supplies which serve line amplifiers will be determined by the power
supply manufacturer's nameplate input rating assuming continuous operation.

The Customer is responsible for notifying the Company of any changes or additions to the
equipment or loads being served under this schedule. Failure to notify the Company of such changes or
additions will result in the termination of service under this schedule and the requirement that service be
provided under one of the Company’s metered service schedules.

If the Customer modifies existing equipment being served under this schedule in a way that allows
for the potential or actual variation in energy usage or installs additional equipment that allows for the
potential or actual variation in energy usage, service under this schedule will be terminated and the
Customer will be required to receive service under one of the Company’s metered service schedules.

With Company approval, municipalities or agencies of federal, state, or county governments may
install equipment that allows for the potential intermittent variation in energy usage at authorized Points of
Delivery. Under these circumstances, the Customer’s bill will include fixed units of the Intermittent Usage
Charge in addition to the Customer’s other Monthly Charges.

The Company is only responsible for supplying energy to the Point of Delivery and, at its expense,
may check energy consumption at any time.
Idaho Power Company Fifteenth RevisedOriginal Sheet No. 40-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. 40-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 40
NON-METERED GENERAL SERVICE
(Continued)

MONTHLY CHARGE

The average monthly kWh of energy usage shall be estimated by the Company, based on the
Customer's electric equipment and one-twelfth of the annual hours of operation thereof. Since the
service provided is non-metered, failure of the Customer's equipment will not be reason for a reduction
in the Monthly Charge. The Monthly Charge shall be computed at the following rate, and may also
include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency
Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).

Energy Charge, per kWh 8.2079.377¢

Minimum Charge, per month $1.502.00

ADDITIONAL CHARGES

Applicable only to municipalities or agencies of federal, state, or county governments with an
authorized Point of Delivery having the potential of intermittent variations in energy usage.

Intermittent Usage Charge, per unit, per month $1.002.00

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Third RevisedOriginal Sheet No. 41-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 41-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2019 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho where street lighting wires and fixtures can be installed on Customer-provided street lighting
facilities or installed on the Company's existing distribution facilities.

APPLICABILITY

Service under this schedule is applicable to service requested or installed by Customers for the
lighting of public streets, public alleys, public grounds, and thoroughfares. Street lighting lamps fixtures
will be energized each night from dusk until dawn.

SERVICE LOCATION AND PERIOD

Street lighting facility locations, type of unit and lamp fixture sizes, as changed from time to time
by written request of the Customer and agreed to by the Company, shall be provided for Customers
receiving service under Options A and B of this schedule. The in-service date for each street lighting
facility shall also be maintained.

The minimum service period for any Company-owned street lighting facility is 10 years. The
Company, upon written notification from the Customer, will remove a Company-owned street lighting
facility:

1. At no cost to the Customer, if such facility has been in service for no less than the
minimum service period. The Company will not grant a request from the Customer for reinstallation of
street lighting service at the same location for a minimum period of two years from the date of removal.

2. Upon payment to the Company of the removal cost, if such facility has been in service
for less than the minimum service period.

SERVICE OPTIONS

"A" - Idaho Power-Owned, Idaho Power-Maintained System - Effective October 1, 2019, high
pressure sodium vapor lighting systems are not available for new installation.

The facilities required for supplying service, including fixture, lamp, control relay, mast
arm for mounting on an existing utility pole, and energy for the operation thereof, are supplied,
installed, owned and maintained by the Company. All necessary repairs and maintenance
work, including group lamp fixture replacement and glassware cleaning, will be performed by
the Company during the regularly scheduled working hours of the Company on the Company’s
schedule. Individual lamps fixtures will be replaced on burnout as soon as reasonably possible
after notification by the Customer and subject to the Company's operating schedules and
requirements.

The Company has light-emitting diodetwo standard high pressure sodium vapor street
lighting (“LED”) fixture options, drop-glass or cut-off (shielded lighting). For each initial LEDhigh
pressure sodium vapor lighting fixture installation, the Customer is required to state, in writing, a
fixture preference. A maintenance-related replacement of a current LEDhigh pressure sodium
vapor fixture will be made with a similar type of drop-glass or cut-off fixture as the one being
replaced unless written notification has been received from the Customer requesting a change
in fixture types.
Idaho Power Company Tenth RevisedOriginal Sheet No. 41-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Ninth Tenth Revised Sheet No. 41-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2019 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
SERVICE OPTIONS (Continued)

"A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued)

Company-owned lighting systems installed on or after June 1, 2004 shall not be
constructed, operated, or modified in such a way as to allow for the potential or actual variation
in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins.

Company-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service –
Variable Energy Charge until the potential for variations in energy usage has been eliminated.
Repair, modification or alteration of these facilities is not permitted.

Accelerated Replacement of Existing Fixtures

In the event a Customer requests the Company perform an accelerated
replacement of existing fixtures with the cut-off fixture, the following charges will apply:

1. The designed cost estimate which includes labor, time, and
mileage costs for the removal of the existing street lighting fixtures.

2. $132.00 per fixture removed from service.

The total charges identified in 1 and 2 above must be paid prior to the beginning
of the fixture replacement and are non-refundable. The accelerated replacement will be
performed by the Company during the regularly scheduled working hours of the
Company and on the Company’s schedule.

Dark Sky Lighting for High Pressure Sodium VapoLED Fixturesr

In the event a Customer requests the Company perform an alteration of existing
LED cut-off fixtures to become dark sky lighting compliant by adding a lens shield to the
replacing the existing drop-lens with a dark sky lighting compliant flat-lensfixture, the
following charges will apply:

1. The designed cost estimate which includes labor, time, and mileage costs
for the alteration of the existing street lighting fixtures.

2. $237.050 per fixture altered for dark sky lighting.

The total charges identified in 1 and 2 above must be paid prior to the beginning
of the fixture alteration and are non-refundable. The fixture alteration to become dark
sky lighting compliant will be performed by the Company during the regularly scheduled
working hours of the Company and on the Company’s schedule.

LED Shield

In the event a Customer requests the Company install a shield on an LED fixture,
the Customer will be responsible for the material cost of the equipment, as well as the
Idaho Power Company Tenth RevisedOriginal Sheet No. 41-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Ninth Tenth Revised Sheet No. 41-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2019 January 1, 2024 1221 West Idaho Street, Boise, Idaho
design cost estimate which includes labor, time, and mileage costs for the alteration of
the existing LED fixture.
Idaho Power Company Fifteenth RevisedOriginal Sheet No. 41-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. 41-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued)

LED Shield

In the event a Customer requests the Company install a shield on an LED fixture,
the Customer will be responsible for the material cost of the equipment, as well as the
design cost estimate which includes labor, time, and mileage costs for the alteration of
the existing LED fixture.

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees).

Lamp Charges, per lampfixture (41A)

_________________________High Pressure Sodium Vapor
LED EquivalentFixture____________________________ Base Rate
Watts Average Lumens Watt (Maximum) Lumen
(Minimum) Base Rate
70 5,540 40 3,600
$11.5548
100 8,550 40 3,600 $11.01
200 19,800 85 7,200
$14.7513.38
250 24,750 140
10,800 $16.0515.34
400 45,000 200 18,000
$18.3019.06

Non-Metered Service – Variable Energy

Energy Charge, per kWh 7.4649.377¢
Pole Charges
For Company-owned poles installed after October 5, 1964 required to be
used for street lighting only:
Charge
Wood pole, per pole $1.81
Steel pole, per pole $7.18

Facilities Charges

Customers assessed a monthly facilities charge prior to June 1, 2004 will
continue to be assessed a monthly facilities charge in accordance with the
charges specified in Schedule 66.

Idaho Power Company Fifteenth RevisedOriginal Sheet No. 41-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. 41-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2022 1221 West Idaho Street, Boise, Idaho

Payment

The monthly bill rendered for service supplied hereunder is payable upon receipt,
and becomes past due 15 days from the date on which rendered.

Idaho Power Company Fifteenth RevisedOriginal Sheet No. 41-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fourteenth Fifteenth Revised Sheet No. 41-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2019 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"CBC" - Customer-Owned, Customer-Maintained System

The Customer's lighting system, including posts or standards, fixtures, initial installation
of lampsfixtures and underground cables with suitable terminals for connection to the
Company's distribution system, is installed, owned, and maintained by the Customer. The
Customer is responsible for notifying the Company of any changes or additions to the lighting
equipment or loads being served under Option C – Non-Metered Service. Failure to notify the
Company of such changes or additions will result in the termination of non-metered service
under Option C and the requirement that service be provided under Option C - Metered Service.

All new Customer-owned lighting systems installed outside of Subdivisions on or after
January 1, 2012 are required to be metered in order to record actual energy usage.

Customer-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service -
Energy Charge until the street lighting system is converted to Metered Service, or until the
potential for variations in energy usage has been eliminated, whichever is sooner.

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees). For non-metered service, the
average monthly kWh of energy usage shall be estimated by the Company based on the
total wattage of the Customer’s lighting system and 4,059 hours of operation.

Non-Metered Service (41C)

6.339

"B" - Customer-Owned, Idaho Power-Maintained System - No New Service and Effective
September 30, 2023, Option B is closed to service.

The Customer's lighting system, including posts or standards, fixtures, initial installation
of lamps and underground cables with suitable terminals for connection to the Company's
distribution system, is installed and owned by the Customer and maintained by Idaho Power.
Customer-owned lighting systems receiving maintenance under Option B must have Idaho
Power standard wattage high pressure sodium vapor lamps installed in all street lighting
fixtures.

Customer-owned systems installed on or after June 1, 2004 which are constructed,
operated, or modified in such a way as to allow for the potential or actual variation in energy
Idaho Power Company Fifteenth RevisedOriginal Sheet No. 41-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fourteenth Fifteenth Revised Sheet No. 41-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2019 January 1, 2024 1221 West Idaho Street, Boise, Idaho
usage, such as through, but not limited to, the use of wired outlets or useable plug-ins, are
required to be metered in order to record actual energy usage.

Customer-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service –
Variable Energy Charge until the street lighting system is converted to Metered Service, or until
the potential for variations in energy usage has been eliminated, whichever is sooner.

Energy and Maintenance Service

Energy and Maintenance Service includes operation of the system, energy, lamp
renewals, cleaning of glassware, and replacement of defective photocells which are
standard to the Company-owned street light units. Service does not include the labor or
material cost of replacing cables, standards, broken glassware or fixtures, painting, or
refinishing of metal poles. Individual lamps will be replaced on burnout as soon as
reasonably possible after notification by the Customer and subject to the Company’s
operating schedules and requirements.

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees).

Idaho Power Company Thirteenth RevisedOriginal Sheet No. 41-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Twelfth Thirteenth Revised Sheet No. 41-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"B" - Customer-Owned, Idaho Power-Maintained System - No New Service (Continued)

Non-Metered Service, per lamp (41B)

Standard High Pressure Sodium Vapor Average Base
Energy and Maintenance Charges: Lumens Rate
70 Watt 5,450 $3.11
100 Watt 8,550 $3.48
200 Watt 19,800 $5.03
250 Watt 24,750 $6.20
400 Watt 45,000 $8.76

Non-Metered Service – Variable Energy

Energy Charge, per kWh 7.464¢

Metered Service, per lamp (41BM)

Standard High Pressure Sodium Vapor
Maintenance Charges:
70 Watt $1.37
100 Watt $1.28
200 Watt $1.27
250 Watt $1.37
400 Watt $1.37

Service Charge, per meter $3.36
Energy Charge, per kWh 5.125¢

Payment

The monthly bill rendered for service supplied hereunder is payable upon receipt, and
becomes past due 15 days from the date on which rendered.

"C" - Customer-Owned, Customer-Maintained System

The Customer's lighting system, including posts or standards, fixtures, initial installation
of lamps and underground cables with suitable terminals for connection to the Company's
distribution system, is installed, owned, and maintained by the Customer. The Customer is
responsible for notifying the Company of any changes or additions to the lighting equipment or
loads being served under Option C – Non-Metered Service. Failure to notify the Company of
such changes or additions will result in the termination of non-metered service under Option C
and the requirement that service be provided under Option C - Metered Service.

Idaho Power Company Fifteenth RevisedOriginal Sheet No. 41-64
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. 41-64

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)

SERVICE OPTIONS (Continued)

"C" - Customer-Owned, Customer-Maintained System (Continued)

All new Customer-owned lighting systems installed outside of Subdivisions on or after
January 1, 2012 are required to be metered in order to record actual energy usage.

Customer-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service -
Energy Charge until the street lighting system is converted to Metered Service, or until the
potential for variations in energy usage has been eliminated, whichever is sooner.

Monthly Charges

The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees). For non-metered service, the
average monthly kWh of energy usage shall be estimated by the Company based on the
total wattage of the Customer’s lighting system and 4,059 hours of operation.

Non-Metered Service (41C)

Energy Charge, per kWh 5.240¢

Metered Service (41CM)

Service Charge, per meter $3.36
Energy Charge, per kWh 5.125¢

Idaho Power Company Fifteenth RevisedOriginal Sheet No. 42-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourteenth Fifteenth Revised Sheet No. 42-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35423 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 42
TRAFFIC CONTROL SIGNAL
LIGHTING SERVICE

APPLICABILITY

Service under this schedule is applicable to Electric Service required for the operation of traffic
control signal lights within the State of Idaho. Traffic control signal lamps are mounted on posts or
standards by means of brackets, mast arms, or cable.

CHARACTER OF SERVICE

The traffic control signal fixtures, including posts or standards, brackets, mast arm, cable,
lamps, control mechanisms, fixtures, service cable, and conduit to the point of, and with suitable
terminals for, connection to the Company's underground or overhead distribution system, are installed,
owned, maintained and operated by the Customer. Service is limited to the supply of energy only for
the operation of traffic control signal lights.

The installation of a meter to record actual energy consumption is required for all new traffic
control signal lighting systems installed on or after June 1, 2004. For traffic control signal lighting
systems installed prior to June 1, 2004 a meter may be installed to record actual usage upon the
mutual consent of the Customer and the Company.

MONTHLY CHARGE

The monthly kWh of energy usage shall be either the amount estimated by the Company based
on the number and size of lamps burning simultaneously in each signal and the average number of
hours per day the signal is operated, or the actual meter reading as applicable. The Monthly Charge
shall be computed at the following rate, and may also include charges as set forth in Schedule 55
(Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for
Municipal Franchise Fees).

Energy Charge, per kWh 5.8157.346¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Third RevisedOriginal Sheet No. 45-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 45-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – October 30, 2019 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 November 29, 2019 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE

AVAILABILITY

Standby Service under this schedule is available at points on the Company's interconnected
system within the State of Idaho where existing facilities of adequate capacity and desired phase and
voltage are available. If additional distribution facilities are required to supply the desired service, those
facilities provided for under Rule H will be provided under the terms and conditions of that rule. To the
extent that additional facilities not provided for under Rule H, including transmission and/or substation
facilities, are required to provide the requested service, special arrangements will be made in a
separate agreement between the Customer and the Company.

Standby Service is available only to Customers taking service under Schedule 9 or Schedule
19.

APPLICABILITY

Service under this schedule is applicable to Customers utilizing on-site generation who request
Standby Service from the Company.

These service provisions are not applicable to service for resale, to service where on-site
generation is used for only emergency supply, or to co-generators or small power producers who have
contracted to supply power and energy.

AGREEMENT

Service shall be provided only after the Uniform Standby Service Agreement is executed by the
Customer and the Company. The term of the Agreement shall be for one year and shall automatically
renew and extend each year, unless terminated under the provisions of the Agreement. The Uniform
Standby Service Agreement will automatically be canceled upon discontinuance of service under
Schedule 9 or Schedule 19.

TYPE OF SERVICE

The Type of Service provided under this schedule is single and/or three-phase at approximately
60 cycles and at the standard voltage available at the Premises to be served.

DEFINITIONS

Supplementary Contract Demand. The firm power contracted for by the Customer under the
Uniform Standby Service Agreement with the Company.

Supplementary Billing Demand. The firm power supplied by the Company on a continuous
basis to supplement the Customer's own generation. Supplementary Billing Demand is equal to the
total average kW supplied during the 15-consecutive-minute period of maximum use during the Billing
Period, adjusted for Power Factor, but not greater than the applicable Supplementary Contract
Demand. Supplementary Billing Demand is billed monthly under the Demand Charge provisions of
Schedule 9 or Schedule 19.

Idaho Power Company Second RevisedOriginal Sheet No. 45-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 45-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– November 1, 2016 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 December 1, 2016 1221 West Idaho Street, Boise, Idaho
Advice No. 16-06

SCHEDULE 45
STANDBY SERVICE
(Continued)

DEFINITIONS (Continued)

Standby Contract Demand. The self-generation backup power contracted for by the Customer
under the Uniform Standby Service Agreement.

Standby Billing Demand. The power supplied by the Company to backup the Customer's own
generation. Standby Billing Demand is equal to the total average kW supplied during the 15-
consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor, less
Supplementary Contract Demand, but not less than zero.

Total Contract Demand. The sum of the Supplementary Contract Demand and the Standby
Contract Demand.

Available Standby Capacity. The Total Contract Demand less the Supplementary Billing
Demand and the Standby Billing Demand, but not more than the Standby Contract Demand.

Excess Demand. The total average kW supplied during the 15-consecutive-minute period of
maximum use each day, adjusted for Power Factor, which exceeds the Total Contract Demand by
more than 5 percent.

Total Energy Requirement. The total energy supplied by the Company for supplementary and
standby purposes. The Total Energy Requirement is billed monthly under the applicable Energy
Charge provisions of Schedule 9 or Schedule 19.

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 90 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing
Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor.

FACILITIES BEYOND THE POINT OF DELIVERY

Any Company investment in Facilities Beyond the Point of Delivery will be provided under the
terms and conditions of Rule M.

PARALLEL OPERATIONS

Parallel operations will only be authorized by the Company under the terms of the Uniform
Standby Service Agreement with the Customer. At the Company’s discretion, the Company will install
a system protection package at the Customer's expense prior to the start of parallel operations. The
Customer will also pay a Maintenance Charge of 0.5961 percent per month times the investment in the
protection package.

Idaho Power Company Eighth RevisedOriginal Sheet No. 45-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Seventh Eighth Revised Sheet No. 45-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 28, 2019 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)
MONTHLY CHARGE

The Monthly Charge for Standby Service is the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge, if any, at the following rates:

Customers taking service under Schedule 9
Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Secondary Service $4.755.45 $4.325.45
Primary Service $3.13 5.43 $2.865.43
Transmission Service $0.793.11 $0.523.11

Standby Demand Charge, per kW of
Standby Billing Demand
Secondary Service $7.209.35 $5.907.61
Primary Service $6.089.37 $5.899.08
Transmission Service $5.75 6.95 $5.566.09

Customers taking service under Schedule 19

Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Primary Service $3.00 6.70 $2.706.70
Transmission Service $0.85 3.11 $0.553.11

Standby Demand Charge, per kW of
Standby Billing Demand
Primary Service $7.09 11.69 $5.7610.31
Transmission Service $6.70 9.61 $5.448.27

Customers taking service under Schedule 9 or Schedule 19

Excess Demand Charge
$0.641.24 per day for each kW times taken in excess of the Total Contract Demand.the sum of
the daily Excess Demands recorded during the Billing Period, plus $6.41 per kW for the highest
Excess Demand recorded during the Billing Period. This charge will not be prorated.

Minimum Charge
The monthly Minimum Charge shall be the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge.

CONTRIBUTION TOWARD MINIMUM CHARGES ON OTHER SCHEDULES

Any Standby Service Charges paid under this schedule shall not be considered in determining
the Minimum Charge under any other Company schedule.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company First RevisedOriginal Sheet No. 45-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 45-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – October 30, 2019 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 November 29, 2019 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)

IDAHO POWER COMPANY
UNIFORM STANDBY SERVICE
AGREEMENT

ACCOUNT NO. _______________________________

THIS AGREEMENT Made this ___________ day of _________________________________,
20______________ between ________________________________________whose billing address
is _______________________________________________ hereinafter called Customer, and Idaho
Power Company, A corporation with its principal office located at 1221 West Idaho Street, Boise, Idaho,
hereinafter called Company:

NOW, THEREFORE, The parties agree as follows:

1. The Company will agree to provide Standby Service to the Customer's facilities located
at or near_________________________________, County of ___________________________, State
of Idaho, in the form of single and/or three-phase, _______________ volt, Electric Service subject to
emergency operating conditions of the Company.

2. The Supplementary Contract Demand provided by this Agreement is _______________
kW. The Company will provide electric power and energy, to supplement the Customer’s on-site
generation, up to the amount of the stated Supplementary Contract Demand. The Standby Contract
Demand provided by this Agreement is___________________ kW. The Company will provide electric
power and energy, in backup to the Customer's on-site generation, up to the amount of the stated
Standby Contract Demand. The Total Contract Demand provided by this Agreement is
_______________ kW.

3. The availability of power in excess of the Total Contract Demand stated in Paragraph 2
above is not guaranteed and its taking by the Customer may result in a complete or partial curtailment
of service to the Customer. The Company has the right to install, at the Customer's expense, any
device necessary to protect the Company's system from damage which may be caused by the taking of
power in excess of the Standby Contract Demand. The Customer will be responsible for any damages
to the Company's system or damages to third parties resulting from the Customer's taking of power in
excess of the Standby Contract Demand.

4. The terms of this Agreement will not become binding upon the parties until signed by
both parties.

5. At the Company's sole discretion and after receiving written authorization from the
Company, the Customer may operate in parallel with the Company's system. Parallel operations will
be in accordance with the Company's Standards for Interconnection and Parallel operations and the
tariff provisions for Standby Service. Any violation of these provisions will result in the immediate
disconnection of the parallel operation.
Idaho Power Company First RevisedOriginal Sheet No. 45-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 45-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– October 30, 2019 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 November 29, 2019 1221 West Idaho Street, Boise, Idaho

SCHEDULE 45
STANDBY SERVICE
(Continued)

IDAHO POWER COMPANY
UNIFORM STANDBY SERVICE
AGREEMENT
(Continued)

6. The initial date of service under this Agreement is subject to the Company's ability to
obtain the required labor, materials, equipment, and satisfactory rights-of-way, and to comply with
governmental regulations.

7. The term of this Agreement will be for one year from and after the Initial Service Date
thereof, and will automatically renew and extend each year thereafter unless written notice of
termination is given by either party to the other not less than 12 months prior to the desired termination
date. This Agreement will automatically be canceled upon discontinuance of service under the
Customer’s retail service schedule.

8. The Customer agrees to hold harmless and indemnify the Company, its officers, agents,
and employees, against all loss, damage, expense and liability to third persons or injury to or death of
person or injury to property proximately caused by the Customer's construction, ownership, operation
or maintenance of, or by failure of, any of the Customer's generating facilities.

9. 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, will be subject to valid laws
and to the regulatory authority and orders, rules and regulations of the Idaho Public Utilities
Commission and such other administrative bodies having jurisdiction.

10. Nothing herein will be construed as limiting the Idaho Public Utilities Commission from
changing any rates, charges, classification or service, or any rules, regulation or conditions relating to
service under this Agreement, or construed as affecting the right of the Company or the Customer to
unilaterally make application to the Commission for any such change.

11. The Company's Schedule 45, any revisions to that schedule, and/or any successor
schedule is to be considered as part of this Agreement.

12. In any action at law or equity commenced under this Agreement and upon which
judgment is rendered, the prevailing party, as part of such judgment, will be entitled to recover all costs,
including reasonable attorneys fees, incurred on account of such action.

13. This Agreement replaces and supersedes the Agreement between the parties dated the
_______________ day of ________________________________, 20 ________.

INITIAL SERVICE DATE ______________________________

(APPROPRIATE SIGNATURES)

Idaho Power Company Fifth RevisedOriginal Sheet No. 46-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 46-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32585 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 July 1, 2012 1221 West Idaho Street, Boise, Idaho

SCHEDULE 46
ALTERNATE DISTRIBUTION
SERVICE

AVAILABILITY

Alternate Distribution Service under this schedule is available at points on the Company's inter-
connected system within the State of Idaho where existing facilities of adequate capacity and desired
phase and voltage are adjacent to the location where Alternate Distribution Service is desired, and where
additional investment by the Company for new distribution facilities is not necessary to supply the
requested service. When additional transmission or substation facilities are required, separate
arrangements will be made between the Customer and the Company.

Alternate Distribution Service is available only to Customers taking Primary Service under
Schedule 9 or 19.

AGREEMENT

Service shall be provided only after the Uniform Alternate Distribution Service Agreement is
executed by the Customer and the Company. The term of the initial agreement shall be dependent upon
the investment required by the Company to provide the Alternate Distribution Service, but shall in no
event be less than one year. The Uniform Alternate Distribution Service Agreement shall automatically
renew and extend each year, unless terminated under the provisions of the Agreement.

TYPE OF SERVICE

Alternate Distribution Service consists of a second distribution circuit to the Customer which
backs up the Customer's regular distribution circuit through an automatic switching device. Alternate
Distribution Service facilities include, but are not limited to, the automatic switching device and that
portion of the distribution substation and the distribution line required to provide the service. The kW of
Alternate Distribution Service capacity shall be specified in the Uniform Alternate Distribution Service
Agreement.

STANDARD OF SERVICE

The Alternate Distribution Service provided under this schedule is not an uninterruptible supply
and is subject to the same standard of service as provided under Rule J.

MONTHLY CHARGES

The Monthly Charge is the sum of the Capacity Charge and the Mileage Charge at the following
rates:

Capacity Charge
$2.403.59 per contracted kW of capacity

Mileage Charge
$.0063 per kW per tenth of a mile in excess of 1.7 8 miles.
Idaho Power Company First RevisedOriginal Sheet No. 46-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 46-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 32426 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2012 1221 West Idaho Street, Boise, Idaho

SCHEDULE 46
ALTERNATE DISTRIBUTION
SERVICE
(Continued)

MONTHLY CHARGES (Continued)

The distribution line will be measured to the nearest tenth of a mile from the Alternate Distribution
Service substation to the automatic switching device.

FACILITIES CHARGE

The automatic switching device will be owned, operated, and maintained by the Company in
consideration of the Customer paying to the Company a monthly Facilities Charge in accordance with the
charges specified in Schedule 66.

CONTRIBUTION TOWARD MINIMUM CHARGE ON OTHER SCHEDULES

Any alternate Distribution Service charges paid under this schedule shall not be considered in
determining the Minimum Charge under any other Company schedule.

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company Original Sheet No. 46-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 46-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
Uniform Alternate Distribution
Service Agreement

LOCATION DESCRIPTION. _______________________ACCOUNT NO.

THIS AGREEMENT between
whose billing address is ____________
hereinafter called Customer, and Idaho Power Company, with its principal office located at 1221 West
Idaho Street, Boise, Idaho, hereinafter called Company:

NOW, THEREFORE, The parties agree as follows:

The Alternate Distribution Service provided through this Agreement consists of a second
distribution circuit to the Customer which backs up the Customer’s regular distribution circuit through an
automatic switching device.

1. This Agreement is subject to the Company’s applicable tariff provisions for Alternate
Distribution Service and is also subject to the Company’s General Rules, Regulations, and Rates as now
or may be hereafter modified and approved by the Idaho Public Utilities Commission.

2. The Company agrees to provide Alternate Distribution Service to the Customer’s loads at
or near , County of , State
of Idaho, in the form of three-phase, volt, Electric Service subject to the emergency
operating conditions of the Company.

3. The Contract Capacity of Alternate Distribution Service provided by this Agreement is
kW. The Company shall reserve this Contract Capacity in the alternate distribution
facilities.

4. The Customer shall pay to the Company a monthly Facilities Charge on the Company’s
investment in the automatic switching device as set forth in the tariff provisions for Alternate Distribution
Service. The amount of this initial investment is set forth in the Distribution Facilities Investment Report
provided by the Company to the Customer. As such investment changes, in order to serve the
Customer’s requirements, the Company shall notify the Customer in writing of additions or deletions of
facilities by forwarding a dated investment notice. The monthly Facilities Charge will be adjusted
accordingly.

5. In the event the Customer requests the Company to remove or reinstall or change the
facilities set forth in the Distribution Facilities Investment Report, the Customer shall pay to the Company
the “non-salvable” cost of such removal, reinstallation or change. Non-salvable cost as used herein is
comprised of the total cost of material, labor, and overheads of installing the facilities, less the difference
between the salvable cost of material removed and the removal labor cost including appropriate overhead
costs.

Idaho Power Company Original Sheet No. 46-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 46-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
Uniform Alternate Distribution
Service Agreement
(Continued)

6. The Company reserves the right to determine the substation and distribution facilities for
both the primary and alternate distribution sources to the Customer for the Contract Capacity specified
under paragraph 3.

7. The initial service date of this Agreement is subject to the Company’s ability to obtain
required labor, materials, equipment, satisfactory rights-of-way, and comply with governmental
regulations.

8. In consideration of the investment required to be made by the Company in the facilities
necessary to provide Alternate Distribution Service, the term of this Agreement shall be for
years from and after the initial service date. The Agreement shall automatically renew and extend each
year thereafter unless written notice of termination is given by either party to the other not less than thirty
(30) days prior to the expiration of the Agreement or any extension of the Agreement. If the Customer
elects not to renew or extend the Agreement, the Customer shall pay the cost of removing the facilities
set forth in the Distribution Facilities Investment Report in accordance with the charges specified under
paragraph 5.

9. This Agreement is subject to valid laws and to the regulatory authority and orders, rules,
and regulations of the Idaho Public Utilities Commission and such other administrative bodies having
jurisdiction.

10. Nothing in this Agreement shall be construed as limiting the Idaho Public Utilities
Commission from changing any rates, charges, classification or service, or any rules, regulation, 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.

Date , 20____.

(APPROPRIATE SIGNATURES)

Idaho Power Company Fifth RevisedOriginal Sheet No. 54-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 54-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35273 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 54
FIXED COST ADJUSTMENT

APPLICABILITY

This schedule is applicable to the electric energy delivered to all Idaho retail Customers receiving
service under Schedules 1, 3, 4, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General
Service).

Customers added to Idaho Power’s system starting January 1, 2022 will be considered new
customers, all other customers are considered existing customers.

FIXED COST PER CUSTOMER RATE

The Fixed Cost per Customer rate (FCC) is determined by dividing the Company’s fixed cost
components for Residential and Small General Service Customers by the average number of Residential
and Small General Service customers, respectively.

The Fixed Cost per Customer Distribution rate (FCC-Dist) is determined by dividing the
Company’s distribution and customer fixed cost components for Residential and Small General Service
Customers by the average number of Residential and Small General Service Customers, respectively.

Residential FCC FCC-Dist
Schedules 1 and 3 $739.20 $287.96
Schedule 5 $739.20 $287.96
Schedule 6 $654.72 $304.20

Small General Service FCC FCC-Dist
Schedule 7 $174.96 $24.02
Schedule 8 $221.61 $63.33

Residential FCC
Effective Date Rate
January 1, 2012 $650.63 per Customer

Residential FCC-Dist
Effective Date Rate
January 1, 2022 $317.72 per Customer

Small General Service FCC
Effective Date Rate
January 1, 2012 $360.57 per Customer

Small General Service FCC-Dist
Effective Date Rate
January 1, 2022 $256.29 per Customer

FIXED COST PER ENERGY RATE

Idaho Power Company Fifth RevisedOriginal Sheet No. 54-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 54-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35273 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho
The Fixed Cost per Energy rate (FCE) is determined by dividing the Company’s fixed cost
components for Residential and Small General Service customers by the weather-normalized energy
load for Residential and Small General Service customers, respectively.

The Fixed Cost per Energy Distribution rate (FCE-Dist) is determined by dividing the Company’s
distribution and customer fixed cost components for Residential and Small General Service customers
by the weather-normalized energy load for Residential and Small General Service customers,
respectively.
Idaho Power Company Sixteenth RevisedOriginal Sheet No. 54-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifteenth Sixteenth Revised Sheet No. 54-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35799 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 54
FIXED COST ADJUSTMENT
(Continued)

FIXED COST PER ENERGY RATE (Continued)

Residential FCE FCE-Dist
Schedules 1 and 3 6.7098¢ per kWh 2.6138¢ per kWh
Schedule 5 – Summer On-Peak 17.5878¢ per kWh 8.3169¢ per kWh
Schedule 5 – Mid-Peak 8.7941¢ per kWh 4.1586¢ per kWh
Schedule 5 – Summer Off-Peak 4.3970¢ per kWh 2.0792¢ per kWh
Schedule 5 – Non-Summer On-Peak 8.5198¢ per kWh 2.9266¢ per kWh
Schedule 5 – Non-Summer Off-Peak 5.6798¢ per kWh 1.9511¢ per kWh
Schedule 6 7.0780¢ per kWh 3.2886¢ per kWh

Small General Service FCE FCE-Dist
Schedule 7 3.8463¢ per kWh 0.5282¢ per kWh
Schedule 8 5.2308¢ per kWh 1.4949¢ per kWh
Residential FCE
Effective Date Rate
January 1, 2012 5.1602¢ per kWh

Residential FCE-Dist
Effective Date Rate
January 1, 2022 2.5199¢ per kWh

Small General Service FCE
Effective Date Rate
January 1, 2012 6.8633¢ per kWh

Small General Service FCE-Dist
Effective Date Rate
January 1, 2022 4.8783¢ per kWh

ALLOWED FIXED COST RECOVERY AMOUNT

The Allowed Fixed Cost Recovery amount is computed by summing 1) the product of the average
number of existing Residential and Small General Service customers multiplied by the appropriate
Residential and Small General Service FCC rate and 2) the product of the average number of new
Residential and Small General Service customers multiplied by the appropriate Residential and Small
General Service FCC-Dist rate.

ACTUAL FIXED COSTS RECOVERED AMOUNT

The Actual Fixed Costs Recovered amount is computed by summing 1) the product of the actual
energy load for existing Residential and Small General Service customers multiplied by the appropriate
Residential and Small General Service FCE rate and 2) the product of the actual energy load for new
Residential and Small General Service customers multiplied by the appropriate Residential and Small
General Service FCE-Dist rate.

FIXED COST ADJUSTMENT
Idaho Power Company Sixteenth RevisedOriginal Sheet No. 54-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifteenth Sixteenth Revised Sheet No. 54-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35799 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

The Fixed Cost Adjustment (FCA) is the difference between the Allowed Fixed Cost Recovery
Amount and the Actual Fixed Costs Recovered Amount divided by the estimated weather-normalized
energy load for the following year for Residential and Small General Service Customers.

The monthly Fixed Cost Adjustment for Residential Service (Schedules 1, 3, 4, 5, and 6) is 0.4402
cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is
0.5541 cents per kWh.

EXPIRATION

The Fixed Cost Adjustment included on this schedule will expire May 31, 2024.
Idaho Power Company Nineteenth RevisedOriginal Sheet No. 55-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Eighteenth Nineteenth Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT

APPLICABILITY

This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company’s schedules and Special Contracts listed within this schedule. These loads are
referred to as "firm" load for purposes of this schedule.

BASE POWER COST AND PROJECTED POWER COST

The Base Power Cost of the Company's rates, expressed in cents per kWh, is computed by
dividing the sum of the Company's power cost components by firm kWh sales. The power cost
components are segmented into three categories as described in the table below:

The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.

BALANCING ADJUSTMENT

The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment is 0.6357 cents per kWh.

EARNINGS SHARING

Order Nos. 30978, 32424, 33149, and 34071 directed the Company to share a portion of its
earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Company’s 2022 earnings were not above the prescribed threshold resulting in a credit of 0.0000 cents
per kWh.

Idaho Power Company Thirteenth RevisedOriginal Sheet No. 55-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Twelfth Thirteenth Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)

POWER COST ADJUSTMENT

The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) the Balancing Adjustment; and 5) Earnings Sharing. The following table calculates
the rates for Categories 1, 2 and 3.

The following table shows the determination of PCA rates for Categories 1, 2, and 3:

Category Description
Base
Power
Cost
Projected
Power
Cost
Difference Sharing
% Rate
(¢ per kWh)
1
The sum of fuel expense and
purchased power expense
(excluding purchases from
cogeneration and small power
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
1.02531.66
1436
1.99191.
991918
0.96670.3
30482 95% 0.91830.3
13958
2
Purchased power expense from
cogeneration and small power
producers.
0.85461.36
9206
1.39531.
395299
0.54070.0
26093 100% 0.54070.0
26093
3 Demand response incentive
payments.
0.07520.06
8447
0.07340.
073423
-
0.00180.0
04976
100%
-
0.00180.0
04976
Total 1.95513.09
9089
3.46063.
460640
1.50550.3
61551 1.45720.3
45027

Idaho Power Company Twelfth RevisedOriginal Sheet No. 55-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Eleventh Twelfth Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)

The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per kWh rates shown below.

Schedule Category
Balancing
djustment
Earnings
Sharing
Total PCA
1 2 3
1
0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000)
2.09290.9807
3 0.91830.3140 0.54070.0261 (0.00180.0050) 0.6357 (0.0000) 2.09290.9807
5 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
6 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
7
0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000)
2.09290.9807
8 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
9S 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
9P 0.91830.3140 0.54070.0261 (0.00180.0050) 0.6357 (0.0000) 2.09290.9807
9T
0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000)
2.09290.9807
15 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
19S
0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000)
2.09290.9807
19P 0.91830.3140 0.54070.0261 (0.00180.0050) 0.6357 (0.0000) 2.09290.9807
19T 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
24 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
40 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
41 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
42 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 (0.0000) 2.09290.9807
26 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 * 2.09290.9807
29 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 * 2.09290.9807
30 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 * 2.09290.9807
32 0.91830.3140 0.54070.0261 (0.0018)0.0050 0.6357 * 2.09290.9807

* Earnings Sharing Credits are applied as monthly amounts per the table below.

Schedule Special Contract Monthly Credit
26 Micron ($0.00)
29 Simplot ($0.00)
30 DOE ($0.00)
32 Simplot-Caldwell ($0.00)

EXPIRATION

The Power Cost Adjustment included on this schedule will expire May 31, 2024.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM

AVAILABILITY

Service under this schedule is available to Customers who have entered into a Uniform Solar
Photovoltaic Service Agreement with the Company. New service under this schedule will not be available
after November 15, 1996.

DEFINITIONS

Photovoltaic System is the solar photovoltaic module(s), the module mounting structure, the
control structure, the control equipment, any necessary wiring, any batteries and/or back-up generator, if
required, and any other equipment necessary to provide service under this schedule. The Company shall
have sole ownership of the Photovoltaic System during the term of the Uniform Solar Photovoltaic Service
Agreement.

Point of Service is the point where the Customer's electric system is connected to the Photovoltaic
System.

Total Installed Cost is the estimated total cost for the installation of, or modification to, the
Photovoltaic System including but not limited to the Company's investment in facilities, labor, material and
supplies, and overheads.

Net Installed Cost is the Total Installed Cost less the Initial Fee.

Customer Site is the installation site and facilities as determined by the Company which are
necessary for the installation of the Photovoltaic System. The Customer Site facilities are not included as
part of the Photovoltaic System unless specifically stated by the Company and included in the Solar
Photovoltaic Facilities Investment Report.

Salvage Value is the market value of the photovoltaic facilities at the time they are removed from
the Customer’s premises.

Facility Termination Charge is the Total Installed Cost of the Photovoltaic System less the sum of
80 percent of the accumulated depreciation and 60 percent of the Salvage Value of the facilities removed
plus the removal cost. In no event will the Facility Termination Charge be less than the removal cost.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM
(Continued)

ELIGIBILITY

Requests for service under this schedule which have a Total Installed Cost of no more than
$50,000, which are located in areas reasonably accessible by standard utility vehicles, and which are cost
effective alternatives are eligible for service under this schedule. In determining eligibility under this
schedule, the Company will consider the remoteness, accessibility, load size, load profile, solar resource,
and solar impediments of the requested site as well as the suitability of the Customer Site. Requests
which have special access requirements may be granted at the discretion of the Company provided that
reasonable alternative access provisions are met and/or the Company is compensated for its special
access related costs. Any special access provisions will be included in an addendum to the Uniform
Solar Photovoltaic Service Agreement. The Company has the sole right to ultimately determine eligibility
under this schedule.

INITIAL FEE

An Initial Fee equal to 5 percent of the Total Installed Cost of the Photovoltaic System is required
from the Customer at the time the Uniform Solar Photovoltaic Service Agreement is executed. If a
modification to the Photovoltaic System which increases the Total Installed Cost is requested subsequent
to the time the Uniform Solar Photovoltaic Service Agreement is executed, an additional Initial Fee equal
to 5 percent of the Total Installed Cost of the modification will be required prior to the installation of such
modification to the Photovoltaic System. The Initial Fee is non-refundable unless the Company
determines that it will not install the Photovoltaic System.

SERVICES PROVIDED

The Photovoltaic System will be specified by the Company based upon the service requirements
requested by the Customer. Upon determination by the Company that the Customer is eligible for service
under this schedule, and upon receipt from the Customer of the Initial Fee, the Company will proceed with
the installation plans for the Photovoltaic System.

All repair and maintenance of the Photovoltaic System will be provided by the Company. Prudent
utility practices will be followed for all necessary repair or maintenance. The Company will use its best
effort to provide the Customer a minimum of 24-hours notice prior to performing preventative
maintenance.

The Customer is responsible for providing the Customer Site and the connections from the Point
of Service to the Customer's facilities, and for permitting the Company appropriate access to the
Photovoltaic System. The Customer Site and Customer connections must be approved by the Company
and must meet all State and Local Codes. The Company may, at its sole discretion, install and/or own
Customer Site facilities and include the cost of such facilities in the Total Installed Cost.

If a back-up generator is included with the Photovoltaic System, the Customer is responsible for
providing, at the Customer's expense, the fuel required for the operation of such generator.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM
(Continued)

SERVICE LIMITATIONS

Electric Service under this schedule is limited to that provided by the Photovoltaic System. The
Company is under no obligation to provide Electric Service to the Customer at any time by means of the
Company's transmission or distribution system.

CUSTOMER NON-COMPLIANCE

Any use by the Customer of the Photovoltaic System not in compliance with the design
specifications for such system or not in compliance with the provisions of this schedule may result in the
removal by the Company of the Photovoltaic System. The Company reserves the right to remove the
Photovoltaic System if the Company determines that the continued use of the facilities by the Customer
poses a threat of injury or damage to persons or property. Non-payment of the monthly charges under
this schedule may also result in the removal by the Company of the Photovoltaic System.

In the event the Company removes the Photovoltaic System under the provisions of this section,
the Customer will be obligated to pay to the Company the Facility Termination Charge.

SOLAR PHOTOVOLTAIC FACILITIES INVESTMENT REPORT

The Total Installed Cost of the Photovoltaic System will be set forth in a Solar Photovoltaic
Facilities Investment Report provided to the Customer. The monthly charge for service under this
schedule is based on the Total Installed Cost, less the Initial Fee, as reflected on this Report. When the
actual book cost of the installed Photovoltaic System has been determined by the Company, the Total
Installed Cost will be adjusted to reflect the actual cost and the corresponding monthly charge will be
reduced if the actual cost is more than 10 percent less than the Total Installed Cost included on the
Report. In no event will the monthly charge be increased if the actual cost is greater than the Total
Installed cost.

PHOTOVOLTAIC SYSTEM MODIFICATIONS

If the Photovoltaic System is modified in order to provide for changes in the Customer’s service
requirements, the Solar Photovoltaic Facilities Investment Report and the corresponding monthly charge
for service will be adjusted to reflect the modification.

Additions. If the Customer requests a modification to the Photovoltaic System, the Customer will
be required to pay an additional Initial Fee equal to 5 percent of the Total Installed Cost of the
modification prior to the installation of the modification.

Removals. If the Customer requests a portion of the Photovoltaic System be removed, the
Customer shall pay to the Company the Facility Termination Charge for that portion of the Photovoltaic
System removed. If the Customer requests the Photovoltaic System in its entirety be removed, the
provisions of the Agreement Termination section below will apply.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM
(Continued)

AGREEMENT TERMINATION

Customer Termination. If the Customer cancels the Uniform Solar Photovoltaic Service
Agreement at the end of any of the five year terms of the Agreement, the Customer shall have the option
of either 1) purchasing the Photovoltaic System at the Company’s Total Installed Cost less accumulated
depreciation, or 2) requesting the Company remove the Photovoltaic System and paying to the Company
the cost of removing the facilities. If the Customer cancels the Uniform Solar Photovoltaic Service
Agreement during the term of the Agreement, the Customer shall pay to the Company the Facility
Termination Charge.

Company Termination. If the Company cancels the Uniform Solar Photovoltaic Service
Agreement at any time and for any reason other than Customer Non-Compliance, the Company shall
offer the Customer the option of either 1) purchasing the Photovoltaic System at the Company’s Total
Installed Cost less accumulated depreciation, or 2) requesting the Company remove the Photovoltaic
System at no cost to the Customer.

CHARGES

The monthly charge for service under this schedule is 1.6 percent times the Net Installed Cost of
the Photovoltaic System as set forth on the Solar Photovoltaic Facilities Investment Report.

Back-up Generator Maintenance Charge. If the hours of usage of a back-up generator included
with the Photovoltaic System exceeds the number of hours of usage specified in the design specifications
by 20 percent or more on an annual basis, the Customer will be responsible for paying the additional
maintenance costs incurred by the Company as a result of such overuse. The Company will notify the
Customer in writing of any observed overuse of the back-up generator.

PAYMENT

The monthly bill rendered for service provided hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM

Idaho Power Company
Uniform Solar Photovoltaic Service
Agreement

DISTRICT ______________________________ ACCOUNT NO. ______________________________

THIS AGREEMENT Made this ____________ day of _________________________, 20______,
between _____________________________________________________, whose billing address is
_________________________________ hereinafter called Customer, and Idaho Power Company, A
corporation with its principal office located at 1221 West Idaho Street, Boise, Idaho, hereinafter called
Company:

NOW THEREFORE, The parties agree as follows:

1. The Company will provide solar photovoltaic service for the Customer's facilities located at
or near _________________________________________, County of _____________________, State
of Idaho.

2. The Customer will:

a. Make an Initial Fee payment to the Company of $_________________ at the time this
Agreement is executed.

b. Provide the installation site and facilities as determined by the Company which are
necessary for the installation of the Photovoltaic System and which are acceptable to the
Company, and the right of the Company for appropriate access to the Company's facilities with
the right of ingress and egress, at no cost to the Company.

3. This Agreement will not become binding upon the parties until signed by both parties.

4. The initial date of service under this Agreement is subject to the Company's ability to
obtain the required labor, materials, and equipment, a satisfactory site, and satisfactory access to the
Photovoltaic System on the Customer's property, and to comply with governmental regulations.

5. The term of this Agreement will be for five years from and after the Initial Service Date
thereof, and will automatically renew for an additional five years each five years thereafter unless
canceled by either party. This Agreement may be canceled 1) by either party after any of the five year
terms provided written notice of termination is given to the other not less than three months prior to the
end of the five year term, or 2) at any time provided both parties agree in writing to the cancellation. In
the event the Company's Schedule 60 is terminated during the term of this Agreement, this Agreement
will automatically be canceled and the Customer will have the option to purchase the Photovoltaic System
at the Company's depreciated book value.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 60-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. Gale, Vice President, Regulatory Affairs
Effective – March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 60
SOLAR PHOTOVOLTAIC SERVICE
PILOT PROGRAM

Idaho Power Company
Uniform Solar Photovoltaic Service
Agreement
(Continued)

6. This Agreement will be binding upon the respective successors and assigns of the
Customer and the Company, provided however, that no assignment by the Customer will be effective
without the Company's prior written consent. The Company's consent will not be unreasonably withheld.

7. This Agreement is subject to valid laws and to the regulatory authority and orders, rules
and regulations of the Idaho Public Utilities Commission as now or may be hereafter modified and
approved by the Idaho Public Utilities Commission.

8. The Company's Schedule 60, as well as Idaho Power Company's General Rules and
Regulations, any revisions to Schedule 60 or to the General Rules and Regulations, and/or any
successor schedule or rules, are to be considered as part of this Agreement.

9. The Company will not be held responsible or liable for any loss, damage, or injury caused
to its Customer or any other persons by the interruption, suspension, or fluctuation in service provided by
the Photovoltaic System.

10. The Customer will agree to protect, defend, and indemnify Idaho Power Company from
and against any costs, damages, or claims arising in any way from any injury to persons or damage to
property resulting from the installation and/or operation of the Photovoltaic System upon Customer's
property, providing such injury to persons or damage to property is not due to the sole negligence of
Idaho Power Company.

11. In any action at law or equity commenced under this Agreement and upon which judgment
is rendered, the prevailing party, as part of such judgment, will be entitled to recover all costs, including
reasonable attorneys fees, incurred on account of such action.

Date __________________________________, 20________
Initial Service Date _____________________________

(APPROPRIATE SIGNATURES)

Idaho Power Company First RevisedOriginal Sheet No. 61-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 61-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 61
PAYMENT FOR HOME WIRING
AUDIT

AVAILABILITY

Service under this schedule is available to residential Customers throughout the Company's
service territory within the State of Idaho who are taking service under Schedules 1, 4, 5, or 6.

SERVICES PROVIDED

A $460 payment is provided by the Company to residential Customers who have a home wiring
audit performed by a licensed electrician. To have a home wiring audit performed, a Customer is
responsible for contacting the Company to request the Home Wiring Audit form and then contacting a
licensed electrician to perform the audit. The Customer is also responsible for ensuring the electrician
performs the audit per the instructions of the Home Wiring Audit form. The charge for the audit will be
established by the electrician and will be billed by the electrician directly to the Customer. The Customer
is responsible for paying the electrician the charge for performing the audit.

The $460 payment is provided to the Customer upon receipt by the Company of the appropriate
copy of the completed Home Wiring Audit form. The Customer is responsible for submitting the Home
Wiring Audit form to the Company.

PURPOSE OF PAYMENT

The purpose of the $460 payment is to assist the Customer in identifying any wiring deficiencies
that may be causing power usage problems. The payment is not an indication that the Company has
performed any analysis as to the safety of the Customer's wiring or that the Company concurs with the
findings of the electrician's wiring audit.

Idaho Power Company Second Revised Original Sheet No. 62-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 62-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35893 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 15, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)

PURPOSE

The Clean Energy Your Way Program (the Program) is an optional, voluntary program designed
to provide eligible Customers and non-customer participants an opportunity to participate in the purchase
of environmentally friendly “green” energy. The Program contains two offerings: 1) The Clean Energy
Your Way – Flexible for Customers and non-customers wishing to procure RECs from existing resources
which may or may not be on Idaho Power’s system; and 2) the Clean Energy Your Way – Construction
option for Customers interested in new renewable energy resources.

DEFINITIONS

Excess Generation is calculated on an hourly basis and represents the REF energy delivered to Idaho
Power’s system that exceeds the REF On-Site Usage.

Net Consumption is calculated on an hourly basis and represents the Customer(s) metered kWh usage
less the line loss-adjusted REF energy delivered to Idaho Power’s system. The Net Consumption cannot
be less than zero.

Renewable Construction Agreement will be the contractual agreement developed between Idaho Power
and a Customer(s) governing the terms, conditions, and pricing of a Clean Energy Your Way –
Construction arrangement.

Renewable Energy Certificate (RECs) will be from renewable projects as defined by the Center for
Resource Solutions Green-e Energy standard and renewable energy will be sourced from projects
located in the Western Electricity Coordinating Council’s geographic area of authority with preference
given to projects located in Idaho Power’s service area and the northwest. Renewable energy types will
be primarily wind and solar but may include other certified types such as geothermal, low-impact
hydroelectric, landfill gas, and biomass.

Renewable Energy Facilities (REFs) are resources fueled by solar, wind, biomass, geothermal, or
hydropower. REFs must be located within Idaho Power’s service area or connected to Idaho Power’s
transmission system and represent new facilities (i.e. facilities not previously constructed). A Seller’s
Generation Facility (as defined by Schedule 72) is ineligible to be selected as a REF.

REF Cost will reflect the cost of the resource interconnected to Idaho Power’s system and procured on
behalf of the participating Customer(s).

REF Credit will reflect the benefit of the REF to Idaho Power’s system, subject to Commission approval.

REF On-Site Usage is calculated on an hourly basis and represents the amount of line loss-adjusted
energy generated by the REF up to a Customer(s) metered kWh usage.

Idaho Power Company First RevisedOriginal Sheet No. 62-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 62-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35893 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 15, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 1: CLEAN ENERGY YOUR WAY - FLEXIBLE

APPLICABILITY

For the purpose of the Clean Energy Your Way – Flexible option, renewable energy will be in the
form of RECs. Service under this option is applicable to all Customers and non-customer participants
who choose to participate in the Program.

REC PURCHASE TERMS

Customer participants will designate one of two billing options upon enrollment. Non-customer
participants may only participate under Option 1.

Option 1: Block

Block Size: One Block equals 100 kWh of RECs

Charge Per Block: $1.00 per month

Option 2: Total Usage

Customers may purchase RECs equal to their monthly usage each month at a price
premium of 1.0 cent per billed kWh.

Option 3: Large Purchase Option

For purchases of 750 MWh or more per year, a tailored agreement may be developed
based on individual Customer preference. Pricing and REC composition will be
individually negotiated in a manner that ensures that the full cost of the REC contract is
borne by the participating Customer(s).

BILLING

For a Customer who chooses Option 1, the monthly bill shall be the number of blocks the
Customer has agreed to purchase multiplied by the Charge Per Block. For a Customer who chooses
Option 2, the monthly bill shall be the Customer’s usage, times the price premium per kWh. For a
Customer who chooses Option 3, the bill shall reflect the terms of the tailored agreement. The bill is in
addition to all other charges contained in the Customer’s applicable tariff schedule. A non-customer
participant will be issued an invoice that reflects their designated purchase amount.

PROGRAM ADMINISTRATION

No funds collected from the Clean Energy Your Way – Flexible option may be used for program
administration (program management). A portion of the funds may be used to support program
communications, participant outreach, and marketing.
Idaho Power Company Original Sheet No. 62.-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 62-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35893 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 15, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 1: CLEAN ENERGY YOUR WAY – FLEXIBLE (Continued)

QUALIFYING INITIATIVES

In an effort to promote local project development and build awareness of renewable energy, if
available, funds collected from the Clean Energy Your Way – Flexible option under REC Options 1 and
2 but not otherwise required to meet program obligations may be distributed to support renewable
demonstration projects at schools located in Idaho Power’s service area. Demonstration projects may
include renewable generation systems, data monitoring, renewable energy curriculum, and teacher
training.

SPECIAL TERMS AND CONDITIONS

Program participants under Options 1 and 2 may apply for, or terminate participation from, the
Clean Energy Your Way – Flexible offering anytime during the year. Participants under Option 3 will be
subject to the terms of the individually negotiated contracts. The Company may limit availability of the
Program subject to available RECs at the cost incurred under the terms described above.

No electric service disconnections will result in the event of non-payment of program
commitments.

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION

APPLICABILITY

Clean Energy Your Way – Construction provides Schedule 19, Large Power Service, and Special
Contract customers an option to buy energy sourced from new renewable projects connected within
Idaho Power’s service area and delivered through Idaho Power’s transmission and distribution system.
This offering is available to individual Customers at a single service point or multiple service points.

Provision of the Construction option is contingent upon Idaho Power and the participating
Customer(s) entering into a Renewable Construction Agreement.

RESOURCE PROCUREMENT

REF procurement will be negotiated by Idaho Power, in consultation with the Customer. REF
characteristics such as generation type and size, construction timing, location, and ownership structure
may vary based on the individual needs of the participating Customer(s) and to ensure non-participating
Customers are held harmless. Customer(s) pursuing the Construction option cannot request to size the
REF greater than 110 percent of the participating service point(s) annual energy amounts. For purposes
of determining annual energy amounts, if available, the most recent 12 months of historical usage will be
used. For new customers, annual energy amounts may be based on a forecast.

The Customer(s) will pay all costs associated with the REF, including but not limited to necessary
studies related to resource acquisition, construction, and integration and interconnection of the resource
with Idaho Power’s system.

Idaho Power Company Original Sheet No. 62-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 62-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35893 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 15, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION (Continued)

CUSTOMER AGREEMENT AND BILLING STRUCTURE

For each billing period, Customer(s) shall incur or receive the following charges/credits:

1. A participating Customer(s)’ Service Charge, Billing Demand, On-Peak Billing Demand, Basic
Load Capacity, and other monthly charges will be charged at the standard rates, charges, and
fees associated with the Customer’s applicable service schedule;

2. Net Consumption shall be charged at the standard rates, charges, and fees associated with
the Customer’s applicable service schedule;

3. The REF On-Site Usage for Special Contract customers shall be charged at a rate in their
respective service schedule and the REF On-Site Usage for Schedule 19 Customers shall be
charged as follows:

Fixed Cost Component of the Retail Energy Charge, per kWh
Time Period Secondary Service Primary Service Transmission Service
Summer On-Peak 3.63200.6951 ¢ 2.49130.6951
¢ 2.43110.6951 ¢
Summer Mid-Peak 2.28980.6951 ¢ 1.40490.6951
¢ 1.37530.6951 ¢
Summer Of -Peak 1.71560.6951 ¢ 0.95030.6951 ¢ 0.92580.6951 ¢
Non-Summer On-Peak 1.5569 ¢ 1.5569 ¢ 1.5569 ¢
Non-Summer Mid-Peak 1.93301.5569 ¢ 1.16291.5569
¢ 1.14411.5569 ¢
Non-Summer Off-Peak 1.40351.5569 ¢ 0.74141.5569
¢ 0.72471.5569 ¢

4. Excess Generation shall be credited to the Customer at a rate contained in the Renewable
Construction Agreement;

5. REF Cost as contained in the Renewable Construction Agreement; and,

6. REF Credit as contained in the Renewable Construction Agreement (if applicable).

REC OWNERSHIP AND ADDITIONAL REC PROCUREMENT

REC ownership will be negotiated on an individual Customer basis. A Customer may elect to
take ownership of the REF’s RECs or elect for Idaho Power to retain ownership and retire the RECs on
the Customer’s behalf.

If the REF generation does not meet 100 percent of the Customer(s)’ consumption on a yearly
basis, the Customer(s) may elect to enter into a separate REC purchase contract to cover the difference
Idaho Power Company Original Sheet No. 62-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 62-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35893 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 15, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 62
CLEAN ENERGY YOUR WAY PROGRAM
(OPTIONAL)
(Continued)

SECTION 2: CLEAN ENERGY YOUR WAY – CONSTRUCTION (Continued)

TERMS AND CONDITIONS

Idaho Power shall have the right to select and reject Program participants at its sole discretion
based on criteria Idaho Power considers necessary to ensure the effective operation of the Program.

The terms and term length of the Renewable Construction Agreement will be determined in a
negotiation between Idaho Power and the Customer(s). The Renewable Construction Agreement will be
subject to Commission approval.

The REF generation cannot be used to offset a Customer(s)’ Basic Load Capacity, Billing Demand
or On-Peak Billing Demand.

The Renewable Construction Agreement must include a Customer(s) financial guarantee to cover
stranded REF costs in the event of Customer default, dissolution, and/or relocation. The guarantee
amount will be negotiated between the Customer(s) and Idaho Power based on the value of the REF to
ensure stranded costs are not shifted to non-participants.

Idaho Power Company Second Revised Sheet No. 63-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 63-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34317 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 26, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-02

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
SUSPENDED

PROGRAM DESCRIPTION

The Community Solar Pilot Program (“Program”) is an optional program that will provide a
limited number of Idaho Power’s Idaho Customers the opportunity to voluntarily subscribe to the
generation output of a 500 kW single-axis tracking community solar array.

AVAILABILITY

The Program is available to Eligible Customers that hold evidence of a Subscription or an
entitlement to the electric generation output of a portion of the community solar array. Participation in
the Program is available on a first-come, first-served basis to all Eligible Customers who complete a
Participant Agreement. Approximately 1,563 Subscriptions will be available. If Idaho Power does not
receive what it deems to be a sufficient number of Subscriptions for the Program, Idaho Power may
terminate the Program and refund the Subscription Fees as set forth under “Refund of Subscription
Fee” in the Participant Agreement.

DEFINITIONS

Eligible Customers. Residential Service (Schedules 1, 5, and 6), Small General Service
(Schedules 7 and 8), Large General Service (Schedule 9), Large Power Service (Schedule 19),
Agricultural Irrigation Service (Schedule 24), Micron Special Contract (Schedule 26), Simplot Special
Contract (Schedule 29), and the Department of Energy Special Contract (Schedule 30) Customers.
Non-metered and lighting accounts may not participate in the Program. Customers must be in Good
Standing with metered electric service accounts with service addresses located in Idaho within Idaho
Power’s service area. Participants must be 18 years of age or older and have full power and authority
to execute the Participation Agreement. Participant must be the customer of record on the Idaho
Power account for the service agreement to which the Subscriptions apply.

Good Standing. At the time of Subscription a Customer is in “Good Standing” if the Customer
does not have a past-due balance of $100 or more that is 60 days or more past due.

Participant. The Customer specified as the Participant in the Participant Agreement is the
Eligible Customer that has received notification of acceptance into the Program, or a successor
Participant designated in accordance with the Participant Agreement.

Participant Agreement. Eligible Customers will be required to sign the Participant Agreement
prior to participating in the Program. Participants will be subject to the terms and conditions of the
Participant Agreement.

Subscription. A “Subscription” is the Participant’s applicable portion of the electricity output
generated by the community solar array developed in connection with the 500 kW project.

Idaho Power Company Second Revised Sheet No. 63-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 63-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34317 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 26, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-02

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)
SUSPENDED

TERM

The Program term will extend 25 years after the date of first production of solar energy on a
non-test basis (Operation Date).

Service on this rate schedule (“Enrollment”) will commence with the first billing cycle following
the later of (i) the approval of the Eligible Customer’s Participant Agreement by the Company, and (ii)
the Operation Date.

SUBSCRIPTION FEE

$562.00 per Subscription.

PAYMENT OF SUBSCRIPTION FEE

Customers have the following payment options:

1. A single upfront payment by check.

2. A single upfront payment made by debit/credit card, mail-in check or money order,
paystation check or money order, or personal on-line bank transfer (“Bill Me”). A Customer who
requests the “Bill Me” option on the Participant Agreement will receive an Idaho Power Company
generated bill, separate from their monthly electric service bill, which must be paid within 30 days. A
convenience fee will be applied to debit/credit card payments.

3. Monthly fee for 2 years (24 months). Residential Service Customers (Schedules 1, 5,
and 6) may choose the monthly fee option and will receive 24 monthly bills, separate from their monthly
electric service bill, which must be paid within 30 days of the monthly invoice date. Payments may be
made by debit/credit card, mail-in check or money order, paystation check or money order, or personal
on-line bank transfer. A convenience fee will be applied to debit/credit card payments. The monthly
Subscription Fee of $26.31 will cover the cost of the Subscription Fee, carrying charges, and an
administration charge of $1.00 per month to reflect the costs of administering this monthly option.
Invoicing of the monthly Subscription Fee will begin with Enrollment.

If the monthly Subscription Fee is not paid within 60 days from the monthly invoice date, the
Customer will be considered in default and the entire Subscription will be transferred to Idaho Power.

PARTICIPATION

To participate in the Program, a Customer must sign and return the Participant Agreement and
elect its method of payment for the Subscription Fee.

Idaho Power Company First Revised Sheet No. 63-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34317 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 26, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-02

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)
SUSPENDED

PARTICIPATION (Continued)

Should a prospective participant have more than one service agreement, the participant must
designate which service agreement and account the Subscription should apply to.

Customers may apply for multiple Subscriptions; however, the estimated total energy output of
the Subscriptions may not exceed 100 percent of the customer’s usage for the prior 12-month period
(on a kWh basis) per service agreement.

If 12 months of usage data is not available, a prospective Participant may estimate its annual
usage, using a method that includes, but is not limited to, usage by similarly sized properties or builder
or architect estimates. All estimates are subject to review and approval by Idaho Power at its sole
discretion.

Customers that Idaho Power at its sole discretion determines are ineligible will be notified
promptly, which Idaho Power expects to occur within 10 business days after such Participant
Agreement is deemed ineligible. In the event a Customer is ineligible to participate, the Subscription
Fee payments received by Idaho Power from ineligible Customers will be returned without interest.

For 60 days following the receipt of a Commission order, nonresidential Customers are limited
to 50 Subscriptions each and 30 percent of total capacity in aggregate. After 60 days following the
receipt of a Commission order, all available capacity may be made available to all eligible customer
classes at the Company’s sole discretion.

SOLAR ENERGY CREDIT

Participants will receive a credit on their monthly bill for retail electric service. The amount of
the Solar Energy Credit will depend on the type of retail metered electric service of the designated
service agreement. The Solar Energy Credit will commence on the first billing cycle after the Operation
Date, and will appear as a “per kWh” line item on each Participant’s bill. The monthly bill credit will be
limited to the Participant’s monthly billed kWh. Any excess production will be carried forward on a kWh
basis. Under no circumstances will any excess production that is unused be converted to monetary
compensation or have value beyond the term of the Program, and upon termination of the Program,
any unused excess production will be forfeited.

The monthly Solar Energy Credit will be equal to the product of (a) the Solar Energy Credit rate
as set forth below and (b) the proportional share measured in kWh of the monthly generation from the
array for that month (as determined by the number of Subscriptions and monthly generation). The
month to which the Solar Energy Credit is applicable may not match the billing period for the retail
electric service billing to which the Solar Energy Credit is applied.

Idaho Power Company Second Revised Sheet No. 63-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 63-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34317 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 26, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-02

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)
SUSPENDED

SOLAR ENERGY CREDIT (Continued)

Schedule Description
Solar Energy Credit
¢ per kWh
1, 5, and 6 Residential Service 3.0246
7 and 8 Small General Service 3.0209
9S Large General Service 2.9936
9P and 9T Large General Service 2.7352
19 Large Power Service 2.7735
24 Irrigation Service 2.6559
26 Micron Special Contract 2.5167
29 Simplot Special Contract 2.5371
30 DOE Special Contract 2.4915

The Power Cost Adjustment rate set forth in Schedule 55 will be applied to the net of the
Participant’s total energy use measured as the Participant’s monthly billed kWh less their proportional
share of the monthly generation measured in kWh from the array for that month.

The Solar Energy Credit rate is subject to change as the average embedded energy cost
reflected in retail rates changes or as otherwise approved by Commission order.

CANCELLATION

The Participant is not eligible to receive a refund of any portion of the Subscription Fee upon
cancellation of the Subscription. The Participant may elect to transfer the Subscription within 60 days
of the Participant terminating service with Idaho Power. If no transfer is requested within such 60-day
period, the Subscription and all benefits of the Subscription will revert to Idaho Power. The
Subscription transfer terms are discussed below.

SUBSCRIPTION TRANSFER

A Participant may elect to transfer the remaining life of the Participant’s Subscription to a new
service agreement or service location for the same Participant that meets the eligibility requirements.
Such transfers are not subject to additional fees.

Upon termination of a Participant’s service, Participants may transfer the remaining life of their
entire Subscription to another Eligible Customer’s service agreement, including an eligible non-profit,
for a $25 fee. Participants with more than one Subscription may transfer their Subscriptions in whole
subscription increments to one or more Eligible Customers for a $25 fee per transfer. A single
Subscription cannot be split for multiple transfers.

Idaho Power Company First Revised Sheet No. 63-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34317 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 26, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-02

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)
SUSPENDED

SUBSCRIPTION TRANSFER (Continued)

Participants that have requested to pay for their Subscription over 24 months, and have
remaining monthly fees at the time of termination of Service, may request to transfer the remaining life
of their Subscription to another Eligible Customer’s service agreement, for the remaining plant balance
(the remaining balance of which is to be assumed in full by the transferee) and a $25 fee.

Participants must notify Idaho Power in writing of their intent to transfer any Subscription(s).
Transfers will only be effective if the recipient satisfies the terms and conditions applicable to the
Subscription and signs the Participant Agreement and assumes all responsibilities associated
therewith.

ENVIRONMENTAL ATTRIBUTES

Idaho Power will retain ownership of the Renewable Energy Certificates and all other
environmental attributes including but not limited to carbon emission reduction credits. The Renewable
Energy Certificates will be retired by Idaho Power on behalf of Participants.

RULES AND REGULATIONS

Service under this Schedule will be in accordance with the standard Rules and Regulations of
the Company as on file with the Idaho Public Utilities Commission.

Idaho Power Company First RevisedOriginal Sheet No. 66-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 66-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. –January 13, 2010John R. Gale, ViceTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2010January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 10-01

SCHEDULE 66
MISCELLANEOUS CHARGES

PURPOSE

The purpose of this schedule is to accumulate all miscellaneous charges that are included in the
Company’s Rules, Regulations, and Rates.

APPLICABILITY

This schedule applies to all Customers taking service under the Company’s Idaho Tariff except
as expressly limited by a rule or a schedule.

CHARGES

RULE D

1. Instrument Transformer Metering

Current transformer

Non-AMI Metering
Single phase
120/240 Volt $214.00
240/480 Volt $247.00
120/208 Volt Network $275.00

Polyphase
120/240 Volt Delta $437.00
240/480 Volt Delta $438.00

120/208 Volt Wye $467.00
277/480 Volt Wye $471.00

AMI Metering
Single phase – AMI metering $307451.00

Polyphase – AMI metering $636898.00

Voltage transformers (secondary voltages only)
Additional cost per voltage transformer $160.00

Primary metering
Work Order costs are applicable.
2. Special Meter Tests Requested by the Customer $85.00

RULE F (all times are stated in Mountain Time)

Idaho Power Company First RevisedOriginal Sheet No. 66-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 66-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. –January 13, 2010John R. Gale, ViceTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2010January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 10-01
1. Service Establishment Charge $30.00

2. Continuous Service Reversion Charge $15.00

3. Field Visit Charge
Schedules 1, 3, 5, 6, 7, 8, 9 $25.00
Schedules 15, 19, 20, 24, 40, 41, 42 $45.00

4. Service Connection Charge
Schedules 1, 3, 5, 6, 7, 8, 9
Monday through Friday
7:30 am to 6:00 pm $30.00
6:01 pm to 9:00 pm $70.00
9:01 pm to 7:29 am $120.00

Company Holidays and Weekends
7:30 am to 9:00 pm $70.00
9:01 pm to 7:29 am $120.00

Idaho Power Company Fourth RevisedOriginal Sheet No. 66-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 66-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.–January 13, 2010John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2010 1221 West Idaho Street, Boise, Idaho
Advice No. 10-01

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

CHARGES (Continued)

RULE F (all times are stated in Mountain Time) (Continued)

Schedules 15, 19, 20, 24, 40, 41, 42
Monday through Friday
7:30 am to 6:00 pm $50.00
6:01 pm to 9:00 pm $95.00
9:01 pm to 7:29 am $175.00

Company Holidays and Weekends
7:30 am to 9:00 pm $95.00
9:01 pm to 7:29 am $175.00

Remote Service Connection
All schedules, all days, all times $8.50

The following is a list of Company-recognized holidays and the dates they are observed: New Year’s
Day (January 1), Martin Luther King Jr. Day (third Monday in January), President’s Day (third Monday
in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday
in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25).
When a holiday falls on Saturday, the previous Friday will be observed. When a holiday falls on a
Sunday, the following Monday will be observed.
2. Off-Site Meter Reading Service

Single-Phase, Non-Demand Metering
Class 200 R300 Register (standard metering) $3.65 per month
Class 320 R300 Register (standard metering) $4.40 per month
Class 10 R300 Register (instrument transformer metering) $4.40 per month

Installation Fee (payable with first monthly payment) $25.00
Removal Fee (if removed within 90 days of installation) $25.00

3. Load Profile Metering

Pulse Output Service
With an existing Electronic Demand Meter $5.00 per month
Without an existing Electronic Demand Meter $13.00 per month

Installation Fee (payable with first monthly payment) $70.00
Removal Fee (if removed within 36 months of installation) $60.00

Idaho Power Company Fourth RevisedOriginal Sheet No. 66-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 66-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.–January 13, 2010John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2010 1221 West Idaho Street, Boise, Idaho
Advice No. 10-01
Load Profile Recording Service
With an existing Electronic Demand Meter $17.50 per month
Without an existing Electronic Demand Meter $25.50 per month

Installation Fee (payable with first monthly payment) $80.00
Removal Fee (if removed within 36 months of installation) $60.00

Enhanced Metering Information Service
With an existing Electronic Demand Meter $5.00 per month
Without an existing Electronic Demand Meter $13.00 per month

Installation Charge (pre-paid) Work Order Costs
Removal Fee (if removed within 36 months of installation) $60.00

4. Special Meter Tests Requested by the Customer $30.00

RULE G

1. Returned Check Charge $20.00
2. Late Payment Charge 12 percent per annum, or
one percent per month.

3. Fractional Period Minimum Billings
Schedules 1, 3, 5, 6, 7, and 8 $3.00
Schedules 9 and 19 Secondary Service Level $3.00
Schedules 9, 19 and 20 Primary and Transmission
Service Levels $50.00
Schedule 24 $3.00

Schedule 40 $2.00
5. Surge Protection Device Services
Surge Protection Device Installation or Removal Charge $43.00
Surge Protection Device Customer Visit Charge $25.00

Idaho Power Company Seventh RevisedOriginal Sheet No. 66-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. 66-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

RULE F (all times are stated in Mountain Time)

1. Service Establishment Charge $20.00

2. Continuous Service Reversion Charge $10.00

3. Field Visit Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9 $20.00
Schedules 15, 19, 20, 24, 40, 41, 42 $40.00

4. Service Connection Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9
Monday through Friday
7:30 am to 6:00 pm $20.00
6:01 pm to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Company Holidays and Weekends
7:30 am to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Schedules 15, 19, 20, 24, 40, 41, 42
Monday through Friday
7:30 am to 6:00 pm $40.00
6:01 pm to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Company Holidays and Weekends
7:30 am to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Remote Service Connection
All schedules, all days, all times $13.00

The following is a list of company-recognized holidays and the dates they are observed: New Year’s
Day (January 1), Martin Luther King Jr. Day (third Monday in January), President’s Day (third Monday
in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday
in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25).
When a holiday falls on Saturday the previous Friday will be observed, when a holiday falls on a
Sunday, the following Monday will be observed.

RULE M

1. Monthly Facilities Charge Rate

Idaho Power Company Seventh RevisedOriginal Sheet No. 66-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Sixth Seventh Revised Sheet No. 66-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022 January 1, 2024 1221 West Idaho Street, Boise, Idaho

Facilities Installed Facilities Installed
31 Years or Less More Than 31 Years
Schedule 9 1.4134% 0.5961%
Schedule 15 1.5062% 1.5062%
Schedule 19 1.4134% 0.5961%
Schedule 24 1.4134% 0.5961%
Schedule 29 1.384% 0.61%
Schedule 32 1.4134% 0.5961%
Schedule 41 1.2113% 1.2113%
Schedule 45 1.4134% 0.5961%
Schedule 46 1.4134% 0.5961%

The monthly Facilities Charge is determined by multiplying the Monthly Facilities Charge
Rate by the Company’s total investment in distribution facilities installed beyond the
Point of Delivery.

Idaho Power Company Fifth RevisedOriginal Sheet No. 66-43
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Seventh Revised Sheet No. 66-43
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

[Intentionally Left Blank]
RULE G (Continued)

3. Fractional Period Minimum Billings
Schedules 1, 3, 4, 5, 6, 7, and 8 $2.00
Schedules 9 and 19 Secondary Service Level $5.00
Schedules 9, 19 and 20 Primary and Transmission
Service Levels $10.00
Schedule 24 $1.50
Schedule 15 $3.00
Schedule 40 $1.50

Idaho Power Company Original Sheet No. 68-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho to all Customer Generators owning or operating DERs, in Parallel with the Company’s system,
that qualify for Schedule 6, Schedule 8, Schedule 84, or Non-Export as defined in this schedule. Non-
Exporting Systems with Total Nameplate Capacity of 3 MVA or greater are required to sign a Uniform
Customer Generator Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to construction, operation, and maintenance of a Customer
Generator System interconnected in Parallel with the Company’s system. In limited circumstances,
certain interconnection requirements included in this schedule may not be applicable when the Company
determines the DER relies on a technology, such as regenerative drives, that does not jeopardize grid
stability or reliability. In making its determination, the Company will evaluate criteria such as the
magnitude and duration of exports.

DEFINITIONS

Company is the Idaho Power Company.

Company-Furnished Facilities are those portions of the Interconnection Facilities funded by the
Customer Generator and provided by the Company.

Customer Generator is a Customer applying to operate or operating a DER in Parallel with the
Company’s system.

Customer Generator-Furnished Facilities are those portions of the Interconnection Facilities
provided by the Customer Generator.

Customer Generator Interconnection Process is the Company’s DER interconnection application,
engineering review, construction, and inspection process for Customer Generator Systems. The
Customer Generator Interconnection Process intends to ensure a safe and reliable generation
interconnection in compliance with all applicable regulatory requirements, good utility practices, and
national safety standards.

Customer Generator System is an Exporting System or a Non-Exporting System.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s
system, including enclosures or other equipment as may be required to ensure that only the Company
will have access to the devices.

Idaho Power Company Original Sheet No. 68-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company.

Feasibility Review is the Company’s standard engineering review of a proposed Customer
Generator System and is intended to ensure the Company’s system is equipped to incorporate the
proposed Customer Generator-Furnished Facilities in a manner that conforms with good utility practices
and the National Electric Safety Code.

Feasibility Study is the Company’s more detailed engineering assessment for DERs as
determined by the Feasibility Review. This study is intended to ensure that the Company’s system is
sufficiently equipped to incorporate proposed DERs in a manner that conforms with good utility practices
and the National Electric Safety Code, including protection coordination and system voltage
management.

Generation Facility means equipment used to produce electric energy at a specific physical
location and service point that qualifies for Schedules 6, 8, 84, or Non-Export. A Generation Facility is a
DER.

Inadvertent Export is the unplanned, unscheduled, and uncompensated transfer of electrical
energy from a Customer’s Non-Exporting System to the Company’s system across the Interconnection
Point.

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Idaho Power Company Original Sheet No. 68-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Non-Exporting System is a Customer-owned DER that limits or prevents electrical energy from
transferring to the Company’s system.

Parallel connection means operating a DER that is connected to and receives voltage from Idaho
Power’s system.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles, or equipment.

Smart Inverter is an inverter that conforms to the latest IEEE 1547 standards and is certified by
the UL 1741 standard, which complies with the latest IEEE 1547 standards.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the
Customer’s DER to the Company’s system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of the Customer Generator System as described in this schedule.

Total Nameplate Capacity is the total of the gross capacity of a DER as designated by the
manufacturer(s) maximum continuous operating rating of the DER in Alternating Current (AC), or as
determined by Idaho Power based on information provided on the System Verification Form.

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Idaho Power Company Original Sheet No. 68-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Customer Generators requesting interconnection to the
Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Customer Generator-Furnished Interconnection Facilities will be constructed and maintained
in a manner as determined by the Company to be in full compliance with all good utility practices, National
Electric Safety Code, conforms to the IEEE 1547 standards, and all other applicable federal, state, and
local safety and electrical codes and standards at all times.

The Customer Generator shall:

1. Upon request, submit proof to the Company that all licenses, permits, inspections, and
approvals necessary for the construction and operation of the Customer’s DER and Interconnection
Facilities under this schedule have been obtained from applicable federal, state, or local authorities.

2. Upon request, submit the designs, plans, specifications, and performance data for the
DER and Customer Generator-Furnished Facilities to the Company for review. The Company’s
acceptance shall not be construed as confirming or endorsing the design, or as a warranty of safety,
durability, or reliability of the DER or Customer Generator-Furnished Facilities. The Company will retain
the right to inspect this equipment at its discretion.

3. Demonstrate to the Company’s satisfaction that the Customer’s DER and Customer
Generator-Furnished Facilities have been completed, and that all features and equipment of the
Customer’s DER and Customer Generator-Furnished Facilities are capable of operating safely to
commence deliveries of energy into the Company’s system.

4. Provide and maintain adequate Protection Equipment sufficient to prevent damage to the
DER, Customer Generator-Furnished Facilities, and any other Customer Generator-owned facilities in
conformance with all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical
and safety codes and requirements as described within this Schedule.

6. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
best effort to arrange repairs and inspections during normal business hours and to notify the Customer
Generator of such arrangements in advance. The Company will provide a telephone number to the
Customer Generator so that the Customer Generator can obtain information about Company activity
impacting the Customer’s DER.

Idaho Power Company Original Sheet No. 68-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Customer DERs. The Disconnection Equipment shall
be installed at an electrical location to allow complete isolation of Customer’s DER and Interconnection
Facilities from the Company’s system. Disconnection Equipment will be installed at an electrical location
on the Customer Generator’s side of the Company’s retail metering point to allow complete isolation of
the Customer’s DER and Interconnection Facilities from the Customer Generator’s other electrical load
and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed and visible within 10 feet of the Interconnection Point or permanently-
posted instructions at the Interconnection Point indicating the exact location of the Disconnection
Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

5. Equipped with a visual disconnect that enables the Company to visually confirm that the
Customer’s and Company’s conductors are physically disconnected. This requires the ability to inspect
the actual conductors visually. Circuit breakers do not satisfy this requirement.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
DER and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior notice
will be provided. In the event of planned repairs, the Company will attempt to notify the Customer
Generator of the time and duration of the planned outage.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event that
any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the
Customer’s Generation Facility are deemed by the Company to be in default or delinquent.
Idaho Power Company Original Sheet No. 68-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

Customer Generators will be subject to disconnection and reconnection charges if the expenses
are incurred as the result of a DER and/or a Customer’s failure to abide by the provisions of Schedule
68.

Disconnection of the service may be necessary. The disconnection may result in the interruption
of both energy deliveries from the Customer Generator System to the Company as well as the interruption
of energy deliveries from the Company to the Customer Generator. Disconnection provisions specific to
Customer Generator Systems less than 3 MVA are described further in Section 2 of this tariff.
Disconnection provisions specific to Non-Exporting Systems greater than 3 MVA are described further in
Section 4 of this tariff.

The Company will establish the settings of Protection Equipment to disconnect the Customer’s
DER and Interconnection Facilities for the protection of the Company’s system and personnel consistent
with good utility practices. If the Customer Generator attempts to modify, adjust or otherwise interfere
with the Protection Equipment or its settings as established by the Company, such action may be grounds
for the Company’s refusal to continue interconnection of the Customer’s DER and Interconnection
Facilities to the Company’s system.

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications, and test results of the Customer Generator-Furnished Facilities to the Company for review
upon request by the Company. Upon receipt of the design and equipment specifications, the Company
will review the design and equipment specifications for conformance with applicable electrical and safety
codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense.

INVERTER REQUIREMENTS

All inverter-based Customer Generator Systems must use a Smart Inverter programmed with the
required settings described in the following section.

Idaho Power Company Original Sheet No. 68-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original Sheet No. 68-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

INVERTER REQUIREMENTS

All Iinverter-based Customer Generator Systems must use a Smart Inverter programmed with the
required settings described in the following section. System Modifications that (1) do not replace or add
inverters, (2) are the result of warranty inverter replacements, or (3) rely on an inverter that is required to
meet the original inverter specifications for the Customer Generator System to properly function, may be
considered exempt from this requirement.

INVERTER SETTINGS

All inverter-based Customer Generator System Smart Inverters will be set for normal operating
performance Category B as defined in IEEE 1547, with the default reactive power control mode set for
the Voltage-reactive power mode and the parameters listed in Table 1. All inverter-based Customer
Generator System Smart Inverters will be set for abnormal voltage and ride through operating
performance Category III as defined in IEEE 1547 using the default settings. The remaining Smart
Inverter settings will be set to the default values specified in IEEE 1547.

Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS
Voltage-reactive power parameters Default Settings
V1 0.92 per unit of nominal voltage
Q1 44% of nameplate apparent power rating, injecting
V2 0.98 per unit of nominal voltage
Q2 0
V3 1.03 per unit of nominal voltage
Q3 0
V4 1.06 per unit of nominal voltage
Q4 44% of nameplate apparent power rating, absorption
Open-loop response time 5 seconds

ENERGY STORAGE DEVICE

Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or
Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that
are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export
energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows:

1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility,
the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC
coupled system can be an Exporting or Non-Exporting system.
Idaho Power Company Original Sheet No. 68-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.
Idaho Power Company Original Sheet No. 68-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

ENERGY STORAGE DEVICE (Continued)

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.

Idaho Power Company Original Sheet No. 68-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
APPLICATION EXPIRATION

Applications that are not completed within one year of the initial Feasibility Review are considered
expired. Customers requesting connection or approval of expired applications are required to resubmit
a completed application form and $100 application fee and are subject to the full application process
described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.

SYSTEM MODIFICATIONS

1. Any modifications to Customer Generator Systems that increase the Total Nameplate
Capacity of the system or modify the system in any way (including inverter replacements) that may impact
the safety or reliability of the Company’s electrical system are considered system modifications for the
purposes of this tariff.

2. Customer Generators planning to make system modifications must submit an application,
$100 fee, and complete the application process according to the procedures required for new
interconnection.

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

Idaho Power Company Original Sheet No. 68-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

2. Customer Generators planning to make system modifications must submit an application,
$100 fee, and complete the application process according to the procedures required for new
interconnection.

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.

b. Option 2: Permanently disable the DER from Parallel operations with the
Company system. Permanent disablement of the DER requires an inspection to be scheduled
with the Company within twelve (12) months from the postmarked notification date. Customers
that do not schedule within this time period will be subject to termination of service.

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Idaho Power Company Original Sheet No. 68-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

Idaho Power Company Original Sheet No. 68-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

The following section is applicable to all Customer Generators with Total Nameplate Capacity
less than 3 MVA.

APPLICATION PROCESS

Customers requesting to interconnect a DER less than 3 MVA are required to complete the
following application process prior to interconnection:

1. Customers must submit a completed application form and a $100 application fee to the
Company. Applications are available on the Company’s website or will be provided to the Customer
upon request.

2. Upon receipt of a completed application and $100 fee, the Company will either (1) provide
the Customer with a written or electronic notification that the application has been received and all
necessary information has been provided, or (2) request the Customer provide forms of documentation
outlined in Section 1.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on project information provided in the
application. The Feasibility Review determines the capability of the Company’s electrical system to
incorporate the proposed Customer Generator System and determines if Upgrades are necessary.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed” notification.

Idaho Power Company Original Sheet No. 68-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original Sheet No. 68-11
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will perform the Feasibility Study within 15 business days. If the results of the Feasibility Study
indicate that Upgrades or Protection Equipment are necessary to accommodate the proposed project,
the Company will notify the Customer of such Upgrades or Protection Equipment.

a. Installation and funding of the construction, installation, and maintenance of
required Protection Equipment will be subject to the following provisions:

i. Protection Equipment Requirements (Rotating Machines): Generation
Facilities up to 500 kVA Total Nameplate Capacity may not require additional Protection
Equipment but will be evaluated on a case-by-case basis. Generation Facilities greater
than 500 kVA Total Nameplate Capacity will require additional Company-Furnished
Protection Equipment.

ii. Protection Equipment Requirements (Other DER): DER up to 3 MVA Total
Nameplate Capacity may not require additional Protection Equipment but will be evaluated
on a case-by-case basis.

iii. When it is determined Company-owned Protection Equipment is required,
the Customer shall pay the actual costs of all required Protection Equipment prior to the
start of Parallel operations. The Customer will also pay a Maintenance Charge of 0.59
percent per month times the investment in the Protection Equipment.

Idaho Power Company Original Sheet No. 68-12
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

5. Following receipt of “Approval to Proceed,” the Customer is responsible for completing the
installation of the Customer Generator System and fulfilling all applicable federal, state, and local
inspection requirements. Customers must also provide the Company with a completed System
Verification Form detailing the specifications of all installed components of the completed Customer
Generator System. System Verification Forms can be found on the Company’s website or will be
provided upon request. Upon completion, the Company reserves the right to request the Customer to
provide forms of documentation outlined in Section 1, verifying that all federal, state, and local
requirements have been met.

6. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, local, and Customer Generation Interconnection Process requirements have
been met, the Company will complete, barring conditions beyond the Company’s control, an on-site
inspection within ten (10) business days for DER with Total Nameplate Capacity of 100 kVA or less and
within twenty (20) business days for DER with Total Nameplate Capacity of greater than 100 kVA.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements. The Company on-site inspection may include the following:

a. Verification that actual installed components correspond to the information
provided on the initial application and the System Verification Form.
b. Verification that the disconnect is functional and reconnection time complies with
IEEE 1547.
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect.
d. Photographic documentation of the installation.
e. Posting of appropriate Company signage.
f. Documentation of the meter number and system configuration.
g. Verification of Smart Inverters.
h. Verification of Total Nameplate Capacity.

7. A return trip charge of $6152.00 will be billed to the Customer each time Company
personnel are dispatched to the job site but are unable to conduct the on-site inspection due to one or
more of the conditions not being met that had been certified as complete by the Customer or installer on
the System Verification Form.

8. Successful completion of the Company on-site inspection constitutes the conclusion of the
application process. The Company must make a reasonable effort to move an Exporting Customer
Generator to the appropriate rate schedule within five (5) business days. Under no circumstances will
the rate change occur more than fifteen (15) business days from the date of the successfully completed
inspection. Upon completion of this process, the Customer will receive confirmation that the application
process has been successfully completed.

Idaho Power Company Original Sheet No. 68-13
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS

APPLICATION PROCESS (Continued)

9. It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving written notice from the Customer indicating Customer’s Generation System
meets all applicable federal, state, and local requirements and is suitable for connection.

In addition to the requirements of Section 1, the following section is applicable to all Customer
Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedule 1 or Schedule 7 that own and/or operate a
Generation Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA or less,
that is operated in Parallel with the Idaho Power System.

NON-EXPORT CONTROL SYSTEM

1. Non-Export Systems must incorporate one of the following three options:

a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, Energy
Management System, or other customer facility hardware or software system(s) may be used to
ensure power is never exported across the Interconnection Point. To ensure that Inadvertent
Export of power is limited to acceptable levels, all of the following conditions must be met: (a)
inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent
Export; (c) the DER must disconnect from the Company’s distribution system or halt energy
production within two seconds after the period of continuous Inadvertent Export exceeds 30
seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur
as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which
results in loss of control signal, loss of control power or single component failure or related control
sensing of the control circuitry.

b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a
reverse power relay protective function must be implemented at the Interconnection Point. The
default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total
Nameplate Capacity, with a maximum 2.0 second time delay.

Idaho Power Company Original Sheet No. 68-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM (Continued)

c. Option 3: (“Minimum Power Protection”): To ensure at least a minimum amount of
power is imported at all times (and, therefore, that power is not exported), an under-power
protective function may be implemented at the Interconnection Point. The default setting for this
non-export control system, when used, shall be 5% (import) of the DERs Total Nameplate
Capacity, with a maximum two (2) second time delay.

2. Control System Failure: Where applicable, any failure of the Customer’s DER control
system for 30 seconds or more, which includes, but is not limited to; the internal transfer relay, energy
management system, or other Customer facility hardware or software system(s) intended to prevent the
reverse power flow, shall cause the Customer’s DER to enter a safe operating mode whereby the
production of energy from the Non-Export DER is autonomously limited to an amount that shall not
cause Inadvertent Export to occur until such time that the Customer has reestablished real power
output control of the non-export control system.

UNAUTHORIZED INADVERTENT EXPORT

Inadvertent Export exceeding three hours of the DER Total Nameplate Capacity in any 30-day
period will be defined as unauthorized Inadvertent Export, and the following steps will be followed for
Customers with Non-Exporting Systems:

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedule 1, Residential and Schedule 7, Small General Non-Exporting
Systems, the Customer Generator must rectify Inadvertent Export within 30 days after receipt of
the notification by Idaho Power that the Non-Exporting System has exceeded the Inadvertent
Export limit. If the Customer Generator has not rectified Inadvertent Export after 30 days, at the
Customer’s election, one of the following actions will occur:

i. The Customer Generator System disconnect will be placed in the open
position until the issue that caused the export is remedied. A Company inspection will be
required before the Non-Exporting System can interconnect to the Company’s system; or,

ii. If the Customer does not elect to open the disconnect, the Customer
Generator will be placed on Schedule 6 or Schedule 8, as appropriate, and subject to
applicable provisions of Section 2. If the Customer elects to be placed on Schedule 6 or
Schedule 8, the Customer will be given the option to submit an additional application and
be moved back to Schedule 1 or Schedule 7, as appropriate, after 180 days.
Idaho Power Company Original Sheet No. 68-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original Sheet No. 68-15
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER

UNAUTHORIZED INADVERTENT EXPORT (Continued)

b. For Schedules other than Schedule 1 or Schedule 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.

In addition to Section 1 and 3, the following section is applicable to all Customers requesting
interconnection of Non-Exporting Systems with Total Nameplate Capacity of 3 MVA or greater.

CUSTOMER GENERATOR INTERCONNECTION PROCESS

1. Customer Generator shall pay the actual costs of all required interconnection studies. Any
difference between the deposit (if required) and the actual cost of the study shall be paid by or refunded
to Customer Generator, as appropriate. If, during the course of preparing a study, the Company incurs
costs in excess of the deposit amount, the Company may require that the deposit amount be replenished
in an amount equal to the festimated costs for completion of the study. If a deposit amount sufficient to
pay for completion of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Customer Generator Interconnection Process.

3. Application. The Customer Generator will submit a completed interconnection application
in the form posted on the Company’s website. The application form includes a general description of the
DER and its location. The application includes payment of an application fee to be applied against costs
the Company incurs to perform the Feasibility Study described below. The amount of the application fee
is $1,000.

4. Study Agreements. Subsequent to the Customer Generator submitting an Application,
the Customer Generator will be offered a series of study agreements. The individual study agreements
establish the time to perform the study, and the deposit the Customer Generator is to provide prior to
commencement of the study. The studies consist of:

Idaho Power Company Original Sheet No. 68-16
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued)

a. The Feasibility Study: The Feasibility Study is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed DER in a manner that
conforms with good utility practices and the National Electric Safety Code. The Feasibility Study
Agreement states that no deposit is required because the application fee covers the deposit.

b. The System Impact Study: For higher complexity projects, the System Impact
Study provides a detailed assessment of the distribution and/or transmission system adequacy to
accommodate the DER through the evaluation of equipment capabilities and electrical
performance requirements. This step may not be necessary for some projects depending on the
size and location of the project. The System Impact Study Agreement includes a deposit of
$2,000 for a distribution system impact study or a $10,000 deposit for a transmission system
impact study.
c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Customer
Generator with an increasingly more refined and detailed report that, among other things, will present a
list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s
cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered
to meet Customer Generator’s construction schedule, the Company will request advance funding by the
Customer Generator to cover these equipment costs.

5. Customer Generator Interconnection Agreement. The Customer Generator
Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of
the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement
template included in this schedule.

INTERCONNECTION FACILITIES REQUIREMENTS

DER greater than 3 MVA Total Nameplate Capacity will require additional Company-Furnished
Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA
Attachment 1.

Idaho Power Company Original Sheet No. 68-17
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

COST OF INTERCONNECTION FACILITIES

The Customer Generator will pay all costs of interconnecting a Generation Facility to the
Company’s system. Costs of interconnection include the costs of furnishing and constructing required
Upgrades, which will be determined pursuant to Rule H. To the extent that additional facilities not
provided for under Rule H, including transmission and/or substation facilities, are required to interconnect
the requested Generation Facility, special arrangements will be made in a separate agreement between
the Customer Generator and the Company.

Each request for interconnection will go through the Customer Generator Interconnection
Process. Throughout the Customer Generator Interconnection Process, the Company will periodically
bill the Customer Generator for engineering costs incurred or obligated. Failure to pay an invoice within
the time specified in the invoice will result in the suspension of work on the interconnection. Customer
Generator can end the Customer Generator Interconnection Process at any time. If Customer Generator
decides to end the Customer Generator Interconnection Process prior to completion, the Company will
either refund any monies held for security that have not been spent or obligated, or issue an invoice to
Customer Generator for costs incurred prior to cancellation.

SYSTEM PROTECTION, DER METERING, AND DER COMMUNICATION MAINTENANCE CHARGE

The Customer shall pay the actual costs of System Protection, DER metering, and DER
communication equipment, as identified in the study process, prior to the start of Parallel operations. The
Customer will pay a Maintenance Charge of 0.59 percent per month times the investment in the System
Protection, DER metering, and DER communication equipment. The Customer Generator will also be
responsible for any applicable monthly charges as outlined in Attachment 1 of the CGIA.

Idaho Power Company Original Sheet No. 68-18
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT

This Uniform Customer Generator Interconnection Agreement (“Agreement”) is entered to be
effective as of the ____ day of __________, 20___ (“Effective Date”), between
____________________________, (“Customer Generator”) and Idaho Power Company (the
“Company”). Customer Generator and the Company may also be referred to individually as a “Party” or
collectively as the “Parties.” Unless explicitly noted otherwise, the term “days” refers to calendar days.

RECITALS

A. Customer Generator owns or operates a Customer Generator System that qualifies for
service under Idaho Power’s Commission-approved Schedule 68 which is subject to change from time
to time pursuant to Commission order.

B. The Customer Generator System to be interconnected and operate in Parallel with the
Company’s system pursuant to this Agreement is more particularly described in Attachment 1.

AGREEMENT

For and in consideration of the mutual covenants and provisions set forth in this Agreement, and
other good and valuable consideration, the receipt of which is hereby acknowledged, the Parties
intending to be legally bound agree as follows:

1. Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth
above, and such Recitals are incorporated herein by this reference.

2. Defined Terms. Capitalized terms not defined in this Agreement shall have the meaning
given to them in Schedule 68.

3. Schedule 68. Schedule 68 is incorporated into this Agreement by this reference and this
Agreement shall be interpreted in conjunction with Schedule 68; in the event of a conflict between
Schedule 68 and this Agreement, Schedule 68 shall prevail. This Agreement and Schedule 68 provide
terms and conditions under which the Customer Generator System will interconnect and operate in
Parallel with the Company’s transmission/distribution system.

4. Entire Agreement. This Agreement, in conjunction with Schedule 68, constitutes the full
and entire understanding and agreement between the Parties regarding the subjects set forth herein and
supersede all prior agreements and understandings related thereto. Nothing in this Agreement is
intended to affect any other agreement between the Company and Customer Generator regarding
subjects outside the terms of this Agreement and Schedule 68.
Idaho Power Company Original Sheet No. 68-19
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

5. Attachments. The following Attachments 1 – 6 are attached hereto and incorporated by
this reference:

Attachment 1 – Description and Costs of the Customer Generator System, Interconnection
Facilities, and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Customer Generator System,
Interconnection Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones for Interconnecting the Customer Generator System.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Customer Generator System.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Customer Generator
System and Best Estimate of Upgrade Costs.

6. Effective Date, Term, Termination and Disconnection.

6.1 Term of Agreement. Unless earlier terminated pursuant to the terms hereof, this
Agreement shall remain in effect from the Effective Date for as long as Customer Generator
System is eligible for service under Schedule 68.

6.2 Termination for Cause. If either Party materially breaches this Agreement and the
material breach is not cured within 10 days after the non-breaching Party gives the breaching
Party written notice thereof, the non-breaching Party may elect to terminate this Agreement by
giving the breaching Party notice of the termination; provided, however, that if the nature of the
breach is such that it could not reasonably be cured within the 10 day period, then the non-
breaching Party may terminate this Agreement immediately upon providing written notice to the
breaching Party. If the Company terminates this Agreement for breach by the Customer
Generator and it is later determined that Customer Generator did not breach the Agreement, or
the breach was excusable, the rights and obligations of the Parties will be the same as if the
termination has been issued for the convenience of the Company pursuant to Section 6.3 below.
Idaho Power Company Original Sheet No. 68-20
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

6.3 Termination for Convenience. The Company may terminate or suspend this
Agreement at any time without cause and without penalty, on 10 days’ written notice to the
Customer Generator. The Customer Generator may terminate or suspend this Agreement at any
time without cause and without penalty by discontinuing Parallel operation of Customer’s
Generator System, or discontinuing taking electric service from the Company, and providing the
Company with 10 days’ written notice of the same.

6.4. Effect of Termination. Upon termination or expiration of this Agreement pursuant
to this Section 6, Idaho Power will disconnect the Customer Generator System from the
Company’s transmission/distribution system. Upon termination or expiration of this Agreement,
all obligations of the Parties (other than those obligations that expressly or by nature survive
termination) shall terminate.

7. Land Rights. Customer Generator hereby grants to Idaho Power for the term of this
Agreement all necessary rights-of-way and easements to install, operate, maintain, replace, and remove
Idaho Power’s Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate and
continuing access rights on the property of Customer Generator. Customer Generator warrants that it
has procured sufficient easements and rights-of-way from third parties so as to provide Idaho Power with
the access described above. All documents granting such easements or rights-of-way shall be subject
to Idaho Power’s approval and in recordable form.

8. Assignment.

8.1 This Agreement may be assigned by either Party upon twenty-one (21) calendar
days prior written notice and opportunity to object by the other Party; provided that:

8.2 Either Party may assign this Agreement without the consent of the other Party to
any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.

8.3 The Customer Generator has the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing financing
for the Generation Facility, provided that the Customer Generator will promptly notify the
Company of any such contingent assignment.
Idaho Power Company Original Sheet No. 68-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

8.4 Any attempted assignment that violates this Section 6 is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall the non-assigning Party’s
obligations be enlarged, in whole or in part, by reason thereof. An assignee is responsible for
meeting the same financial, credit, and insurance obligations as the Customer Generator. Where
required, consent to assignment will not be unreasonably withheld, conditioned or delayed.

9. Indemnity. To the fullest extent permitted by law, Customer Generator shall indemnify,
defend, reimburse, and hold harmless the Company and its successors and their respective directors,
officers, members, employees, representatives, and agents (collectively, the “Indemnitees”), from, for,
and against any and all third-party allegations, claims, liens, liabilities, losses, demands, damages,
expenses, suits, actions, proceedings, judgments, and costs of any kind whatsoever, including, without
limitation, settlement costs, court costs, and attorneys’ and expert witness fees and expenses
(collectively, “Damages”), whether actual or merely alleged, and whether directly incurred or incurred by
a third party, arising out of, or relating to a) the negligent acts, omissions, or willful misconduct of
Customer Generator, b) a violation of federal or state law, regulation, statute, or ordinance, or c)
Customer Generator’s material breach of this Agreement. If the Company seeks indemnification from
the Customer Generator, the Company shall: (i) notify Customer Generator of the assertion of any claim;
(ii) provide reasonable assistance (at Customer Generator’s expense) in connection with the defense;
and (iii) be entitled to pre-approve any settlement.

9.1 The Parties shall at all times indemnify, defend, and hold the other Party harmless
from, any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of or resulting from
the other Party’s action or failure to meet its obligations under this Agreement on behalf of the
indemnifying Party, except in cases of gross negligence or intentional wrongdoing by the
indemnified Party.

9.2 If an indemnified person is entitled to indemnification under this article as a result
of a claim by a third party, and the indemnifying Party fails, after notice and reasonable opportunity
to proceed under this article, to assume the defense of such claim, such indemnified person may
at the expense of the indemnifying Party contest, settle or consent to the entry of any judgment
with respect to, or pay in full, such claim. Failure to defend is a Material Breach.
Idaho Power Company Original Sheet No. 68-22
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

9.3 If an indemnifying party is obligated to indemnify and hold any indemnified person
harmless under this article, the amount owing to the indemnified person shall be the amount of
such indemnified person’s actual loss, net of any insurance or other recovery.

10. Force Majeure Event. Neither Party shall be liable for any breach, default, or delay in
the performance of the obligations under this Agreement if and to the extent such default or delay is
caused by fire, flood, earthquake, elements of nature or acts of God, riots, civil disorder, rebellions or
revolutions, strikes, lockouts or other industrial disturbances, unanticipated changes in governmental
laws and regulations, or any other cause beyond the reasonable control of such Party (a “Force Majeure
Event”); provided the non-performing Party is without fault in causing such breach, default, or delay, and
such breach, default or delay could not have been prevented by reasonable precautions and cannot
reasonably be circumvented by the non-performing Party through the use of alternate sources, work-
around plans, or other means. The Party claiming a Force Majeure Event must give the other Party
immediate written notice, no later than five (5) calendar days of the Party’s discovery of the Force Majeure
Event, and the time for resumption of performance (if applicable) by that Party. The suspension of
performance shall be of no greater scope and of no longer duration than is required by the Force Majeure
Event.

11. Insurance. During the term of this Agreement, Customer Generator shall secure and
continuously carry the following insurance coverage Comprehensive General Liability Insurance for both
bodily injury and property damage with limits equal to $1,000,000, each occurrence, combined single
limit. The deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property. Such insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

Idaho Power Company Original Sheet No. 68-23
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

11.1 An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and

11.2 A provision stating that such policy shall not be canceled, or the limits of liability
reduced without sixty (60) days’ prior written notice to Idaho Power.

11.1 Customer Generator to Provide Certificate of Insurance. As required in
Paragraph 11 herein and annually thereafter, Customer Generator shall furnish the Company a
certificate of insurance, together with the endorsements required therein, evidencing the coverage
as set forth above.

11.2 Customer Generator to Notify Idaho Power of Loss of Coverage. If the insurance
coverage required by Paragraph 11.1 shall lapse for any reason, Customer Generator will
immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific
reason for the lapse and the steps Customer Generator is taking to reinstate the coverage.
Failure to provide this notice and to expeditiously reinstate or replace the coverage will constitute
grounds for a temporary disconnection under Section 9.2 and will be a Material Breach.

12. Miscellaneous.

12.1 Governing Law. This Agreement shall be interpreted, applied and enforced in
accordance with the laws of the State of Idaho without regard to its conflicts of law principles.

12.2 Net Salvage Value. If removal of the Interconnection Facilities is required, within
sixty (60) days after the termination or expiration of this Agreement, Idaho Power will provide
Customer Generator an estimate of the remaining value of the Company-Furnished
Interconnection Facilities required under Schedule 68 and/or described in this Agreement, less
the cost of removal and transfer to Idaho Power’s warehouse (“Net Salvage Value”). If Customer
Generator elects not to purchase the Interconnection Facilities from the Company, Idaho Power
will reimburse the Customer Generator the Net Salvage Value as estimated by Idaho Power.
Customer Generator shall invoice Idaho Power for the same and Customer Generator shall have
the right to offset the invoice amount with amounts due to Idaho Power from Customer Generator.

Idaho Power Company Original Sheet No. 68-24
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13. Notices. Any changes to the below contacts must be made via written notice pursuant to
Section 13.1.

13.1 Written Notice. Where required herein, written notice shall be deemed to have
been duly served when (i) delivered in person, or (ii) sent by mail or courier, return receipt
requested, at the address for each Party as follows:

If to the Customer Generator:
Customer Generator:
Attention:
Address:
City: State: Zip:

If to the Company:
Company:
Attention:
Address:
City: State: Zip:

Idaho Power Company Original Sheet No. 68-25
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13.2 Designated Operating Representative. The Parties may also designate an
operating representative to communicate regarding administration of this Agreement, as well as
operations and maintenance of such Party’s facilities; provided that, any “written notice” required
by this Agreement must be made as set forth in the above Section 13.1.

Customer Generator’s Operating Representative:
Customer Generator:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

IN WITNESS WHEREOF, the Parties hereto enter this Uniform Customer Generator Agreement
to be effective as of the Effective Date.

Idaho Power Company
Print:
Sign:
Title:
Date:

Customer Generator
Print:
Sign:
Title:
Date:
Idaho Power Company Original Sheet No. 68-26
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 1

Description and Costs of the Customer Generator System, Interconnection Facilities and Metering
Equipment

In this attachment, the Customer Generator System and Interconnection Facilities, including
Special Facilities and upgrades, are itemized and identified as being owned by the Customer Generator
or the Company. As provided in Schedule 68, Cost of Interconnection Facilities, the Company will provide
a best estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Customer Generator System, Interconnection Facilities, Metering
Equipment and Upgrades

Idaho Power Company Original Sheet No. 68-27
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Customer Generator________________________ Date______________

Idaho Power Company Original Sheet No. 68-28
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 68-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Customer Generator’s Needs

The Company shall also provide requirements that must be met by the Customer Generator prior
to initiating Parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Customer Generator, based upon information provided by the Customer Generator. The Company will
specify the equipment required on the Company’s system to meet the Facility’s reactive power
requirements. These specifications will include but not be limited to equipment specifications, equipment
location, Company-provided equipment, Customer Generator provided equipment, and all costs
associated with the equipment, design and installation of the Company-provided equipment. The
equipment specifications and requirements will become an integral part of this Agreement. The
Company-owned equipment will be maintained by the Company, with total cost of purchase, installation,
operation, and maintenance, including administrative cost to be reimbursed to the Company by the
Customer Generator. Payment of these costs will be in accordance with Schedule 68 and the total
reactive power cost will be included in the calculation of the monthly facilities charge.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 68, this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection
Agreement. The interconnection procedures and requirements for customer-owned generation facilities,
including those that qualify for Schedule 6, Schedule 8, Schedule 84 or non-export customer generation
are governed by Schedule 68.

APPLICABILITY

Service under this schedule applies to the construction, operation, maintenance, Upgrade,
Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely
interconnect a Seller's Generation Facility to the Company's system.

DEFINITIONS

Additional Applicant is a person or entity whose request for electrical connection requires the
Company to utilize existing Interconnection Facilities which are subject to a Vested Interest.

Company is the Idaho Power Company.

Connected Load is the combined input peak kW of installed energy generation plus the total
nameplate kW rating of the Seller or Ccustomer's motors and other energy consuming devices.

Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or
construction of Company furnished Interconnection Facilities.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Seller to the Company's system,
including enclosures or other equipment as may be required to ensure that only the Company will have
access to certain of the devices.

First Energy Date is the date when the Seller begins delivering energy to the Company's system.

Generation Facility means equipment used to produce electric energy at a specific physical
location which meets the requirements to be a Qualifying Facility.

Generator Interconnection Process is the Company’s Generation Facility interconnection
application, engineering review and construction process. The intent of the Generator Interconnection
Process is to ensure a safe and reliable generation interconnection in compliance with all applicable
regulatory requirements, good utility practices and national safety standards.

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow the delivery of energy from the Seller's
Generation Facility to the Company's system, including, but not limited to, Special Facilities,
Disconnection Equipment and Metering Equipment.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

DEFINITIONS (Continued)

Interconnection Point is the point where the Seller’s conductors connect to the facilities owned by
the Company.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Seller's Generation Facility and the Company's system. These facilities are not
eligible for Vested Interest.

OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open Access
Transmission Tariff.

Protection Equipment is the circuit-interrupting device, protective relaying, and associated
instrument transformers.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of
the Code of Federal Regulations.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles or equipment.

Seller is a non-utility generator who has contracted or will contract with the Company to
interconnect a Generation Facility to the Company’s system to sell electric energy to the Company.

Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the
Seller.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the Seller's
Generation Facility to the Company's system.

Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of
Seller-Furnished Facilities.

Upgrades are those improvements to the Company's existing system which are reasonably
required by good practices and the National Electric Safety Code to safely interconnect the Seller’s
Generation Facility. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Vested Interest is the claim for refund that a Seller, person or entity or Additional Applicant holds
in a specific portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years
from the date the Company completes construction of its portion of the Interconnection Facilities unless
fully refunded earlier.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Sellers requesting interconnection to the Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to
be in full compliance with all good utility practices, National Electric Safety Code, and all other applicable
federal, state, and local safety and electrical codes and standards at all times.

The Seller shall:

1. Submit proof to the Company that all licenses, permits, inspections, and approvals
necessary for the construction and operation of the Seller's Generation and Interconnection Facilities
under this schedule have been obtained from applicable federal, state, or local authorities.

2. Submit the designs, plans, specifications, and performance data for the Generation
Facility and Seller-Furnished Facilities to the Company for review. The Company’s acceptance shall not
be construed as confirming or endorsing the design, or as a warranty of safety, durability, or reliability of
the Generation Facility or Seller-Furnished Facilities. The Company will retain the right to inspect this
equipment at its discretion.

3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and Seller-
Furnished Facilities have been completed, and that all features and equipment of the Seller’s Generation
Facility and Seller-Furnished Facilities are capable of operating safely to commence deliveries of Energy
into the Company's system.

4. Provide and maintain adequate protective equipment sufficient to prevent damage to the
Generation Facility, Seller-Furnished Facilities and any other Seller-owned facilities in conformance with
all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical
and safety codes and requirements as described within this Schedule.

6. Provide a 24-hour telephone contact(s). This contact will be used by the Company to
arrange for repairs and inspections or in case of an emergency. The Company will make its best effort
to arrange repairs and inspections during normal business hours and to notify the Seller of such
arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller
can obtain information about Company activity impacting the Seller’s facility.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection
Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation
and Interconnection Facilities from the Company’s system.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed at a location within 10 feet of the Interconnection Point or exact,
permanent instructions posted at the Interconnection Point indicating the precise location of the
Disconnection Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the Seller's
operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or may
otherwise adversely affect the Company's equipment, personnel, or service to its customers, the
Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by
operation of the disconnection device or by any other means the Company deems necessary to
adequately disconnect the Seller’s Generation and Interconnection Facilities from the Company’s system.
At such time as the unsafe condition is remedied or other condition adversely affecting the Company is
resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Seller’s Generation and Interconnection Facilities in the event
of any planned or unplanned maintenance or repair of the Company’s system connected to the Seller’s
Generation and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior
notice will be provided. In the event of planned repairs, the Company will attempt to notify the Seller of
the time and duration of the planned outage.

The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in the
event that any terms and conditions of any applicable Company tariff or contract enabling the
interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or
delinquent.

All expenses of disconnection and reconnection incurred by the Company will be billed to the
Seller.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

The Company will establish the settings of Protection Equipment to disconnect the Seller’s
Generation Facility and Interconnection Facilities for the protection of the Company’s system and
personnel consistent with good utility practices. If the Seller attempts to modify, adjust or otherwise
interfere with the protection equipment or its settings as established by the Company, such action may
be grounds for the Company's refusal to continue interconnection of the Seller’s Generation and
Interconnection Facilities to the Company’s system.

GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Seller’s Generation Facility and/or Interconnection Facilities designating
the existence of the Seller’s Generation Facility as required by good utility practices.

3. The Seller will be required to submit all specific designs, equipment specifications, and
test results of the Seller-Furnished Facilities to the Company for review. Upon receipt of the design and
equipment specifications, the Company will review the design and equipment specifications for
conformance with applicable electrical and safety codes and standards.

OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as well as
any Seller-Furnished Facilities transferred to the Company.

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES

The following section is applicable to all Sellers requesting interconnection of non-utility
generation.

SPECIFIC PROJECT REQUIREMENTS

1. Generation Facilities Less than 1 MW Nameplate Rating

The following requirements are for Generation Facilities with nameplate ratings of less than 1
MW.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

SPECIFIC PROJECT REQUIREMENTS (Continued)

a. The Company shall procure, install, own and maintain Metering Equipment to
record energy deliveries to the Company. This metering will be separate from any other metering
of the Seller’s load and may be located on either side of the Interconnection Point. All acquisition,
installation, maintenance, inspection and testing costs related to Meter Equipment installed to
measure the Seller’s energy deliveries to the Company shall be borne by the Seller.

b. The Seller is responsible for all costs incurred by the Company for the review,
evaluation and testing of Seller supplied designs and equipment regardless as to the outcome of
the review or test results.

c. The Seller, upon completion of installation and prior to interconnection of the
Generation Facility to the Company’s system, will provide the Company with certification from a
professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility
and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable
electrical and safety codes to enable safe and reliable operation.

d. The Seller will obtain and provide to the Company an annual certification and
testing by a professional engineer licensed in the State of Idaho, certifying the ongoing
compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the
Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In
the event the Company does not receive and accept the annual certification within thirty (30) days
of the annual anniversary date of the agreement, the project will be disconnected from the
Company’s system until such time as the certification is completed and accepted by the Company.

e. In addition to the requirements specified in sections a through d, Generation
Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the
following:

i. If the Company owns the transformer interconnecting the Seller’s
Generation Facility, then the Seller may own and maintain a secondary voltage
disconnection device that can be operated by both the Seller and the Company.

ii. If the Seller owns the transformer interconnecting the Seller’s Generation
Facility, then the Company will own, operate and maintain a primary voltage disconnection
device at the Seller’s expense.

iii. The Company will construct, own, operate and maintain all protective
relays and any associated equipment required to operate the protective relays.

2. Generation Facilities Greater Than 1 MW Nameplate Rating

The Company will own, maintain and operate all Interconnection Facilities and Disconnection
Equipment at the Seller’s expense.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS

1. Seller shall pay the actual costs of all required interconnection studies. Any difference
between the deposit (if required) and the actual cost of the study shall be paid by or refunded to Seller,
as appropriate. If, during the course of preparing a study, the Company incurs costs in excess of the
deposit amount, the Company may require that the deposit amount be replenished in an amount equal
to the estimated costs for completion of the study. If a deposit amount sufficient to pay for completion of
the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Generator Interconnection Process.

3. The deposit amounts for Generation Facilities up to 30 MW are specified in this schedule.
Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-approved Large
Generator Interconnection Procedures posted on the Company’s website.

4. Application. The Seller will submit a completed interconnection application in the form
posted on the Company’s website. The application form includes a general description of the Generation
Facility and its location. The application includes payment of an application fee to be applied against
costs the Company incurs to perform the Feasibility Study described below. The amount of the
application fee is $1,000 for a Generation Facility up to 30 MW.

5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the
Seller will be offered a series of study agreements. The individual study agreements establish the time
to perform the study and the deposit the Seller is to provide prior to commencement of the study. The
deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for
unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of:

a. The Feasibility Study: The Feasibility Study includes a general review of project
impact, e.g. exceeding equipment capabilities and vi olation of electrical performance
requirements. The Feasibility Study Agreement states that no deposit is required, since the
deposit is covered by the application fee.

b. The System Impact Study: The System Impact Study provides a detailed
assessment of the distribution and/or transmission system adequacy to accommodate the
Generation Facility through the evaluation of equipment capabilities and electrical performance
requirements. This step may not be necessary for some projects depending on the size and
location of the project. The System Impact Study Agreement includes a deposit of $2,000 for a
distribution system impact study or a $10,000 deposit for a transmission system impact study.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Seller with
an increasingly more refined and detailed report that, among other things, will present a list of required
Interconnection Facilities and a non-binding, good faith estimate of Seller’s cost responsibility for the
Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s
construction schedule, the Company will request advance funding by the Seller to cover these equipment
costs.

6. Generator Interconnection Agreement. The Generator Interconnection Agreement
(“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the Uniform
Interconnection Agreement template included in this schedule.

COST OF INTERCONNECTION FACILITIES

All Interconnection Facilities provided under this schedule will be valued at the Company's
Construction Cost and/or the Transfer Cost for vesting purposes, as well as for operation and
maintenance payment obligations.

PAYMENT FOR INTERCONNECTION FACILITIES

Unless specifically agreed otherwise by written agreement between the Seller and the Company,
the Seller will pay all costs of interconnecting a Generation Facility to the Company's system. Costs of
interconnection include the costs of furnishing and constructing required Interconnection Facilities,
including Upgrades.

Each request for interconnection will go through the Generator Interconnection Process.
Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for costs
incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result in
suspension of work on the interconnection and if the suspension of work extends beyond thirty (30)
calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end
the Generator Interconnection Process at any time. If Seller decides to end the Generator
Interconnection Process prior to completion, the Company will either refund any monies held for security
that have not been spent or obligated, or issue an invoice to Seller for costs incurred prior to cancellation.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

SECURITY FOR PAYMENT OF INTERCONNECTION COSTS

Sellers will provide adequate security for payment of the costs of the Generator Interconnection
Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance
with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s
OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following
ways

1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are not
required to provide additional security. The Company’s minimum credit standards for unsecured credit
are described in Attachment L to the OATT.

2. Sellers that do not meet the credit worthiness standards for unsecured credit will be
notified of the reason for the determination and shall be given the option to provide alternative security
acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow account,
provide a letter of credit or provide guarantee of payment by another person or entity which meets the
credit worthiness standards for unsecured credit. Arrangements for alternative security must be
acceptable to Idaho Power.

TRANSFER OF INTERCONNECTION FACILITIES

Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate
ratings greater than 100 kW.

1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires
to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply:

a. Prior to the beginning of construction, the Seller shall cause the contractor that is
constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the
Company as an additional insured in the amount of not less than $1,000,000 under the
contractor's general liability policy.

b. The Company will provide the Seller's contractor with construction and material
specifications and will have final approval of the design of the Seller-Furnished Facilities.

c. During construction and upon completion, the Company will inspect the Seller-
Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne
by the Seller.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

TRANSFER OF INTERCONNECTION FACILITIES (Continued)

d. If the Seller-Furnished Facilities meet the Company's design, material and
construction specifications, are free from defects in materials and workmanship, and the Seller
has provided the Company with acceptable easements, bills of sale and assurance against labor
or materials liens, the Company will accept ownership effective as of the First Energy Date. In
the bill of sale, the Seller will warrant to the Company that the Seller-Furnished Facilities are free
of any liens or encumbrances and will be free from any defects in materials and workmanship for
a period of one year from the First Energy Date.

2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and the
Company desires to accept any Seller-Furnished Facilities, the following will apply:

a. The Company will inspect the facilities proposed for sale to determine if they meet
the Company's design, material and construction specifications.

b. The Company will determine the Transfer Cost of such facilities. The Transfer
Cost will be equal to the depreciated Construction Cost the Company would have incurred if it
had originally constructed the facilities plus the cost, if any, of bringing the facilities into
compliance with the Company's design, material and construction specifications. Depreciation of
the facilities proposed for transfer will be determined on the same basis as the Company
depreciates its own facilities in accordance with the appropriate FERC account numbers for the
type and size of line or equipment involved. The time period used for the calculation of the
depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer
date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the same
time, the Company will pay the Seller in cash an amount equal to the depreciated Construction
Cost.

c. As a condition of the Company's acceptance, the Seller will provide the Company
with acceptable easements, bills of sale and acceptable assurance against labor and material
liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and
encumbrances and will be free from any defects in materials and workmanship for a period of one
year from the date of transfer.

d. Effective as of the date of the transfer, the Company will operate and maintain the
transferred facilities.

VESTED INTEREST

A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company
completes construction of its portion of the Interconnection Facilities.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-11
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

VESTED INTEREST (Continued)

1. The Company will provide a refund payment to each the Seller, person or entity holding a
Vested Interest in Company-owned Interconnection Facilities when an Additional Applicant shares use
of those Interconnection Facilities.

2. The refund payment will be based on one of the following formulaoptions:

Option One – An Additional Applicant may choose to pay an amount determined by this
equation:

Vested Interest Amount = A x B x C where:

Linear Connected Original
Refund = Footage x Load/Peak Generation x Interconnection
Ratio Ratio Cost

A = Load Ratio: The Connected Load of the Additional Applicant divided by the
sum of the Connected Load of the Additional Applicant and the Connected
Load of the Seller, person or entity holding a Vested Interest.

a.B = The Linear Footage Ratio isDistance Ratio: tThe length of jointly
used Special Facilities divided by the length of the vested Special Facilities.

b. The Connected Load/Peak Generation Ratio is the Connected Load or Peak
Generation of the Additional Applicant divided by the sum of the Connected Load or Peak
Generation of the Additional Applicant and all other Connected Loads and/or Peak Generation on
the Special Facilities.

cC = . The Original Interconnection Cost: is the sum of the Company's
Construction Cost and any Transfer Costs for the Interconnection Facilities to
which the Additional Applicant intends to connect and share usage.

Option Two – An Additional Applicant may choose to pay the current Vested Interest, in
which case the Vested Interest will transfer to the Additional Applicant and, as such, the
Additional Applicant will hold the Vested Interest and be eligible to receive Vested Interest
refunds.

If Option One is selected, the Additional Applicant has no Vested Interest and the previous Vested
Interest holder remains the Vested Interest holder. The Vested Interest holder’s Vested Interest
will be reduced by the newest Additional Applicant’s payment.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-11
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
3. The Additional Applicant will pay the Company the amount of the Vested Interest
refund(s). Additional Applicants making Vested Interest payments are in turn eligible to receive refunds
within the 5 year limit described above.

4. The Seller, person or entity holding a Vested Interest will be eligible to receive refunds up
to 80 percent of their original interconnection cost. Additional Applicants that become Vested Interest
holders will be eligible to receive refunds up to their total contribution less 20 percent of the original
interconnection cost. Vested Interest refunds will be funded by no more than 4 Additional Applicants
during the 5-year period following the date the Company completes construction of its portion of the
Interconnection Facilities.

4.

5. Vested Interest refund payments may be waived by notifying the Company in writing.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as well as
any Seller-Furnished Facilities transferred to the Company. Seller will pay the Company a monthly
operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost
paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in
accordance with the following tables:

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-12
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifth Fourth Revised Sheet No. 72-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSESVESTED INTEREST (Continued)

5. In no circumstance will Vested Interest refunds will not exceed 100 percent of the
refundable portion of any party's cash payment to the Company.

5. Vested Interest refund payments may be waived by notifying the Company in writing.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as
well as any Seller-Furnished Facilities transferred to the Company. Seller will pay the Company a
monthly operation and maintenance charge equal to a percentage of the Construction Cost and Transfer
Cost paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date
in accordance with the following tables:

56. Vested Interest refund payments may be waived by notifying the Company in writing.

7. All existing agreements’ refund provisions will be governed and administered under the
provisions in effect at the time the agreement was entered into between the Company and Seller or
Additional Applicant.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities, as well as
any Seller-Furnished Facilities transferred to the Company. Seller will pay the Company a monthly
operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost
paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in
accordance with the following tables:

TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV
Yea 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40% 0.41%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67% 0.70%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14% 0.40%

TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-12
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fifth Fourth Revised Sheet No. 72-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70%

The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a
percentage of the applicable original interconnection investment. These monthly operating and
maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for Table
1 and 0.70% for Table 2.
Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the operation
and maintenance charge related to those existing Interconnection Facilities for the Seller’s
interconnection will be computed at the applicable levelized rate designated at 36+ years.

The cost upon which an individual Seller's operation and maintenance charge is based will be
reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the
monthly operation and maintenance charge on the amount they paid as an Additional Applicant.

Seller-Furnished Facilities not transferred to the Company will be operated and maintained by the
Seller at the Seller's sole risk and expense.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-13
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the operation
and maintenance charge related to those existing Interconnection Facilities for the Seller’s
interconnection will be computed at the applicable levelized rate designated at 36+ years.

The cost upon which an individual Seller's operation and maintenance charge is based will be
reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the
monthly operation and maintenance charge on the amount they paid as an Additional Applicant.

Seller-Furnished Facilities not transferred to the Company will be operated and maintained by the
Seller at the Seller's sole risk and expense.

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)

This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________,
20___, between ____________________________, hereinafter called “Seller,” and Idaho Power
Company, hereinafter called “Company.”

RECITALS

A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power’s Commission-approved Schedule 72 and any successor schedule.

B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.

AGREEMENTS

1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72
or in the body of this Agreement.

2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions under
which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the Company’s
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72, Schedule
72 shall prevail.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s
power and other services that Seller may require will be covered under separate agreements. Nothing
in this Agreement is intended to affect any other agreement between the Company and Seller.

4. Attached to this Agreement and included by reference are the following:

Attachment 1 – Description and Costs of the Generation Facility, Interconnection Facilities,
and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones For Interconnecting the Generation Facility.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Seller’s Generation Facility.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.

5. Effective Date, Term, Termination and Disconnection.

5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller’s Generation Facility is eligible for service under Schedule 72.

5.2 Termination.

5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.

5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation
Facility will be disconnected from the Company’s transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities and
obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-15
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation
Facility will be disconnected from the Company’s transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities and
obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.

5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of
the practices, methods and acts engaged in or approved by a significant portion of the electric
industry during the relevant time period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made,
could have been expected to accomplish the desired result at a reasonable cost consistent with
good business practices, reliability, safety and expedition. Good Utility Practice is not intended
to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to be
acceptable practices, methods, or acts generally accepted in the region. Good Utility Practice
includes compliance with WECC or NERC requirements. Payment of lost revenue resulting from
temporary disconnection shall be governed by the power purchase agreement.

5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company’s transmission/distribution system, the Company’s
Interconnection Facilities or the equipment of the Company’s customers; or (3) that, in the
case of the Seller, is imminently likely (as determined in a non-discriminatory manner) to
cause a material adverse effect on the reliability and security of, or damage to, the
Generation Facility or the Seller’s Interconnection Facilities. Under Emergency
Conditions, either the Company or the Seller may immediately suspend interconnection
service and temporarily disconnect the Generation Facility. The Company shall notify the
Seller promptly when it becomes aware of an Emergency Condition that may reasonably
be expected to affect the Seller’s operation of the Generation Facility. The Seller shall
notify the Company promptly when it becomes aware of an Emergency Condition that may
reasonably be expected to affect the Company’s equipment or service to the Company’s
customers. To the extent information is known, the notification shall describe the
Emergency Condition, the extent of the damage or deficiency, the expected effect on the
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-15
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
operation of both Parties' facilities and operations, its anticipated duration, and the
necessary corrective action.

5.3.1 Emergency Conditions. "Emergency Condition" means a condition or situation: (1) that in the
judgment of the Party making the claim is imminently likely to endanger life or property; or
(2) that, in the case of the Company, is imminently likely (as determined in a non-
discriminatory manner) to cause a material adverse effect on the security of, or damage
to the Company’s transmission/distribution system, the Company’s Interconnection
Facilities or the equipment of the Company’s customers; or (3) that, in the case of the
Seller, is imminently likely (as determined in a non-discriminatory manner) to cause a
material adverse effect on the reliability and security of, or damage to, the Generation
Facility or the Seller’s Interconnection Facilities. Under Emergency Conditions, either the
Company or the Seller may immediately suspend interconnection service and temporarily
disconnect the Generation Facility. The Company shall notify the Seller promptly when it
becomes aware of an Emergency Condition that may reasonably be expected to affect
the Seller’s operation of the Generation Facility. The Seller shall notify the Company
promptly when it becomes aware of an Emergency Condition that may reasonably be
expected to affect the Company’s equipment or service to the Company’s customers. To
the extent information is known, the notification shall describe the Emergency Condition,
the extent of the damage or deficiency, the expected effect on the operation of both
Parties' facilities and operations, its anticipated duration, and the necessary corrective
action.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-16
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller’s Generation Facility and
temporarily disconnect the Generation Facility from the Company’s
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company’s transmission/distribution system. The Company will make
a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system, and/or
unplanned events, the Company may not be able to provide notice to the Seller prior to
interruption, curtailment or reduction of electrical energy deliveries to the Company. The
Company shall use reasonable efforts to coordinate such reduction or temporary
disconnection with the Seller.

5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller’s timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller’s
preferred schedule. Neither Party shall unreasonably withhold acceptance of the proposed
maintenance schedule.

5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage to
the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller’s protective relays will provide back-up protection for Idaho Power’s
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.

5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year, Seller shall
submit a written proposed maintenance schedule of significant Facility maintenance for
that calendar year and the Company and Seller shall mutually agree as to the acceptability
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-16
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
of the proposed schedule. The Parties determination as to the acceptability of the Seller’s
timetable for scheduled maintenance will take into consideration Good Utility Practices,
Idaho Power system requirements and the Seller’s preferred schedule. Neither Party shall
unreasonably withhold acceptance of the proposed maintenance schedule.

5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage to
the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller’s protective relays will provide back-up protection for Idaho Power’s
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
Idaho Power Company Fifth RevisedOriginal Sheet No. 72-17
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 72-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company’s
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of the
disconnection.

5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller’s Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company’s transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect within
a reasonable time, the Company may disconnect the Generation Facility. The Company
shall provide the Seller with reasonable notice of such disconnection, unless the
provisions of Article 5.3.1 apply.

5.3.7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility that
may have a material impact on the safety or reliability of the Company’s
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company’s prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.

5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company’s
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
Idaho Power Company Fifth RevisedOriginal Sheet No. 72-17
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 72-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
5.3.7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility that
may have a material impact on the safety or reliability of the Company’s
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company’s prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.

5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company’s
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
Idaho Power Company Fifth RevisedOriginal Sheet No. 72-18
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 72-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified nominal
operating voltage level.

5.4 Land Rights.

5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the term
of this Agreement all necessary rights-of-way and easements to install, operate, maintain,
replace, and remove Idaho Power's Metering Equipment, Interconnection Equipment,
Disconnection Equipment, Protection Equipment and other Special Facilities necessary or
useful to this Agreement, including adequate and continuing access rights on property of
Seller. Seller warrants that it has procured sufficient easements and rights-of-way from
third parties so as to provide Idaho Power with the access described above. All documents
granting such easements or rights-of-way shall be subject to Idaho Power's approval and
in recordable form.

5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct and
maintain Seller-furnished Interconnection Facilities upon, along and over any and all public
roads, streets and highways, then the use by Seller of such public right-of-way shall be
subordinate to any future use by Idaho Power of such public right-of-way for construction
and/or maintenance of electric distribution and transmission facilities and Idaho Power
may claim use of such public right-of-way for such purposes at any time. Except as
required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for
exercising its rights under this Paragraph 5.4.2.
5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to avoid the adverse
environmental and operating impacts that would occur as a result of duplicate electric lines
Idaho Power Company Fifth RevisedOriginal Sheet No. 72-18
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 72-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
being constructed in close proximity. Therefore, subject to Idaho Power's compliance with
Paragraph 5.4.4, Seller agrees that should Seller seek and receive from any local, state
or federal governmental body the right to erect, construct and maintain Seller-furnished
Interconnection Facilities upon, along and over any and all public roads, streets and
highways, then the use by Seller of such public right-of-way shall be subordinate to any
future use by Idaho Power of such public right-of-way for construction and/or maintenance
of electric distribution and transmission facilities and Idaho Power may claim use of such
public right-of-way for such purposes at any time. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under this
Paragraph 5.4.2.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-19
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under this
Paragraph 5.4.3.

5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior to
Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties agree
that the exercise by Idaho Power of any of the rights enumerated in Paragraphs 5.4.2 and
5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility Practices, (2)
equitably share the costs of installing, owning and operating jointly used facilities and
rights-of-way. If the Parties are unable to agree on the method of apportioning these
costs, the dispute will be submitted to the Commission for resolution and the decision of
the Commission will be binding on the Parties, and (3) shall provide Seller with an
interconnection to Idaho Power's system of equal capacity and durability as existed prior
to Idaho Power exercising its rights under this Paragraph 5.4.

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default.

6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party;
provided that:

6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-19
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided that:

6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-20
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages
and Default.

6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided that:

6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.

6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.

6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any indirect,
special, consequential, or punitive damages, except as authorized by this Agreement.

6.3 Indemnity.

6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.

6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions relating
to injury to or death of any person or damage to property, demand, suits, recoveries, costs
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-20
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
and expenses, court costs, attorney fees, and all other obligations by or to third parties,
arising out of or resulting from the other Party's action or failure to meet its obligations
under this Agreement on behalf of the indemnifying Party, except in cases of gross
negligence or intentional wrongdoing by the indemnified Party.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party harmless from,
any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and
expenses, court costs, attorney fees, and all other obligations by or to third parties, arising
out of or resulting from the other Party's action or failure to meet its obligations under this
Agreement on behalf of the indemnifying Party, except in cases of gross negligence or
intentional wrongdoing by the indemnified Party.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.3.3 If an indemnified person is entitled to indemnification under this article as a
result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such claim,
such indemnified person may at the expense of the indemnifying Party contest, settle or
consent to the entry of any judgment with respect to, or pay in full, such claim. Failure to
defend is a Material Breach.

6.3.4 If an indemnifying party is obligated to indemnify and hold any indemnified
person harmless under this article, the amount owing to the indemnified person shall be
the amount of such indemnified person's actual loss, net of any insurance or other
recovery.

6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation as
to which the indemnity provided for in this article may apply, the indemnified person shall
notify the indemnifying party of such fact. Any failure of or delay in such notification shall
be a Material Breach and shall not affect a Party's indemnification obligation unless such
failure or delay is materially prejudicial to the indemnifying party.

6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of Force
Majeure” means any cause beyond the control of the Seller or of the Company which, despite the
exercise of due diligence, such Party is unable to prevent or overcome. Force Majeure includes,
but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil strife, strikes and other
labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or changes in law or
regulation occurring after the Operation Date, which, by the exercise of reasonable foresight such
party could not reasonably have been expected to avoid and by the exercise of due diligence, it
shall be unable to overcome. If either Party is rendered wholly or in part unable to perform its
obligations under this Agreement because of an event of Force Majeure, both Parties shall be
excused from whatever performance is affected by the event of Force Majeure, provided that:

(1) The non-performing Party shall, as soon as is reasonably possible after the
occurrence of the Force Majeure, give the other Party written notice describing the particulars of
the occurrence.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of Force Majeure”
means any cause beyond the control of the Seller or of the Company which, despite the exercise
of due diligence, such Party is unable to prevent or overcome. Force Majeure includes, but is not
limited to, acts of God, fire, flood, storms, wars, hostilities, civil strife, strikes and other labor
disturbances, earthquakes, fires, lightning, epidemics, sabotage, or changes in law or regulation
occurring after the Operation Date, which, by the exercise of reasonable foresight such party
could not reasonably have been expected to avoid and by the exercise of due diligence, it shall
be unable to overcome. If either Party is rendered wholly or in part unable to perform its
obligations under this Agreement because of an event of Force Majeure, both Parties shall be
excused from whatever performance is affected by the event of Force Majeure, provided that:

(1) The non-performing Party shall, as soon as is reasonably possible after the
occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-22
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.

(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.

6.5 Default and Material Breaches.

6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a “Default” or an “Event of Default”), the non-defaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty (60)
days after service of such notice, or if the defaulting Party reasonably demonstrates to the
other Party that the Default can be cured within a commercially reasonable time but not
within such sixty (60) day period and then fails to diligently pursue such cure, then, the
non-defaulting Party may, at its option, terminate this Agreement and/or pursue its legal
or equitable remedies.

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.5.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material Breaches
must be cured as expeditiously as possible following occurrence of the breach.

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do not apply to
Defaults identified in this Agreement as Material Breaches. Material Breaches must be
cured as expeditiously as possible following occurrence of the breach.

7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry
the following insurance coverage:

7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-22
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property.

7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-23
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material Breaches
must be cured as expeditiously as possible following occurrence of the breach.

7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry
the following insurance coverage:

7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.

7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and

(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days’ prior written notice to Idaho Power.

7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.

7.4 Seller to Notify Idaho Power of Loss of Coverage. If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.

8. Miscellaneous.

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-23
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
8.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the State of Idaho without regard to its conflicts
of law principles.

8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value of those
Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or described in this
Agreement, less the cost of removal and transfer to Idaho Power's nearest warehouse, if the
Interconnection Facilities will be removed. If Seller elects not to obtain ownership of the Interconnection
Facilities but instead wishes that Idaho Power reimburse the Seller for said Facilities the Seller may
invoice Idaho Power for the net salvage value as estimated by Idaho Power and Idaho Power shall pay
such amount to Seller within thirty (30) days after receipt of the invoice. Seller shall have the right to
offset the invoice amount against any present or future payments due Idaho Power.
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-24
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

8. Miscellaneous.

8.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the State of Idaho without regard to
its conflicts of law principles.

8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value of
those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power’s nearest
warehouse (Net Salvage Value). If the Seller elects to obtain ownership of the Idaho Power
furnished Interconnection Facilities, the Seller will decline the Net Salvage Value and execute an
Asset Transfer Agreement. If the Seller elects not to obtain ownership of the Idaho Power
furnished Interconnection Facilities, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the nNet sSalvage vValue as
estimated by Idaho Power, and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due to Idaho Power.

9. Notices.

9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered via email, delivered by recognized national
courrier service, or sent by first class mail, postage prepaid, to the person specified below:

If to the Seller:
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-24
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
If to the Company:
Company
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.2 Billing and Payment. Billings and payments shall be sent to the addresses set out
below:

Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-25
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

If to the Seller:
Seller:
Attention:
Address:
City: State: Zip:
Phone: FaxEmail:

If to the Company:
Company
Attention:

Address:
City: State: Zip:
Phone: FaxEmail:

9.2 Billing and Payment. Billings and payments shall be sent to the addresses set out
below:

Seller:
Attention:
Address:
City: State: Zip:
Phone: FaxEmail:

Company:
Attention:
Address:
City: State: Zip:
Phone: FaxEmail:

9.3 Designated Operating Representative. The Parties may also designate operating representatives
to conduct the communications which may be necessary or convenient for the administration of
this Agreement. This person will also serve as the point of contact with respect to operations and
maintenance of the Party’s facilities.

Seller’s Operating Representative:
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-25
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.5 Changes to the Notice Information. Either Party may change this information by
giving five Business Days written notice prior to the effective date of the change.

10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.

For the Company
Name:
Title:
Date:

For the Seller
Name:
Title:
Date:
Idaho Power Company Fourth RevisedOriginal Sheet No. 72-26
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Seller’s Operating Representative:

Seller:
Attention:
Address:
City: State: Zip:
Phone: FaxEmail:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: FaxEmail:

9.54 Changes to the Notice Information. Either Party may change this information by
giving five Business Days written notice prior to the effective date of the change.

10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.

For the Company
Name:
Title:
Date:

For the Seller
Name:
Title:
Date:

Attachment 1

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-26
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment

In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and Metering
Equipment.

Attachment 2

One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades

Idaho Power Company Fourth RevisedOriginal Sheet No. 732-27
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Attachment 1

Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment

In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and Metering
Equipment.

Attachment 2

One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
Idaho Power Company Fourth RevisedOriginal Sheet No. 732-27
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Seller________________________ Date______________

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-28
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-28 thru 72-34
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
GENERATOR INTERCONNECTIONS
TO PURPA QUALIFYING FACILITY SELLERS
(Continued)

SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)
AGREEMENTS (Continued)

Agreed to by:

For the Company __________________________ Date______________

For the Seller________________________ Date______________

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Seller’s Needs

The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Seller, based upon information provided by the Seller. The Company will specify the equipment required
on the Company’s system to meet the Facility’s reactive power requirements. These specifications will
include, but not be limited to, equipment specifications, equipment location, Company-provided
equipment, Seller provided equipment, and all costs associated with the equipment, design and
installation of the Company-provided equipment. The equipment specifications and requirements will
become an integral part of this Agreement. The Company-owned equipment will be maintained by the
Company, with total cost of purchase, installation, operation, and maintenance, including administrative
cost to be reimbursed to the Company by the Seller. Payment of these costs will be in accordance with
Schedule 72 and the total reactive power cost will be included in the calculation of the Monthly Operation
and Maintenance Charges specified in Schedule 72.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

Idaho Power Company Fourth RevisedOriginal Sheet No. 72-28
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 72-28 thru 72-34
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 23, 2021 1221 West Idaho Street, Boise, Idaho
As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

Idaho Power Company Original Sheet No. 73-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-1

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO

AVAILABILITY

In all electric territory area served by the Company in the State of Idaho.

APPLICABILITY

To Qualifying Facilities that intend to sell their output to the Company by either (i)
interconnecting to the Company’s electrical system at an interconnection point within the State of Idaho,
or (ii) delivering the output to the Company at a point of delivery (“POD”) on the Company’s electrical
system within the State of Idaho.

A Customer selling the output of any Qualifying Facility (including both Qualifying Facilities with
a maximum generating capability equal to or less than the Eligibility Cap and Qualifying Facilities with a
maximum generating capability greater than the Eligibility Cap) will be required to enter into a written
Energy Sales Agreement (“ESA”) with the Company in accordance with the contracting procedures set
forth in this tariff. Any such ESA is subject to the approval of the Idaho Public Utilities Commission
(“Commission”).

DEFINITIONS

Customer as used herein means any individual, partnership, corporation, association,
governmental agency, political subdivision, municipality, or other entity that owns an existing or
proposed Qualifying Facility.

Cogeneration Facility means equipment used to produce electric energy and forms of useful
thermal energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes,
through the sequential use of energy.

Daily Shape Adjustment means an adjustment to rates based on a difference between Heavy
Load rates and Light Load rates of $7.28 per MWh as established in Commission Order No. 30415.

Eligibility Cap means for all Qualifying Facilities except wind and solar Qualifying Facilities, 10
average megawatts in any given month. For wind and solar Qualifying Facilities, “Eligibility Cap”
means 100 kilowatts (“kW”) nameplate capacity.

Facility means the electric generation facility owned by the Customer that is located on the
Customer’s side of the POD, and all facilities ancillary and appurtenant thereto, including
interconnection equipment.

Heavy Load Hours means the daily hours from hour ending 0700 – 2200 Mountain Time, (16
hours) excluding all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

Light Load Hours means the daily hours from hour ending 2300 – 0600 Mountain Time, (8
hours) plus all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

Idaho Power Company Original Sheet No. 73-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-2

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

DEFINITIONS (continued)

Integration Charges means the Commission-approved integration charge applicable to any
intermittent generation resource, including but not limited to, wind and solar generation.

Generator Interconnection Agreement (“GIA”). The interconnection agreement that specifies
terms, conditions, and requirements of interconnecting to the Company electrical system, which will
include, but not be limited to, all requirements as specified by Schedule 72. If the Facility is not
interconnecting directly to the Company electrical system, the Facility will not have a GIA with the
Company but instead will have a similar agreement with the utility the Facility is directly interconnecting
to.

Point of Delivery (POD) is the location specified in the GIA (or Transmission Agreement) where
the Company’s and the Seller’s (or third-party transmission provider’s) electrical facilities are
interconnected and the energy from the Qualifying Facility is delivered to the Company electrical
system.

Qualifying Facility shall mean a Cogeneration Facility or a Small Power Production Facility that
is a “Qualifying Facility” as that term is defined in the Federal Energy Regulatory Commission’s
regulations, 18 C.F.R. § 292.101(b)(1) (2010), as may be amended or superseded.

Seasonal Factors means a seasonal weighting of 0.735 for the months of March, April, and
May, 1.20 for the months of July, August, November, and December and 1.00 for the months of
January, February, June, September, and October.

Small Power Production Facility means the equipment used to produce output including electric
energy solely by the use of biomass, waste, solar power, wind, water, or any other renewable resource.

Transmission Agreement. If the Facility is not directly interconnected to the Company electrical
system, the Facility must obtain firm transmission rights from the appropriate utility(s) to deliver the
Facility’s maximum capacity to an agreed to POD on the Company electrical system for the full term of
the ESA. This agreement(s) shall have minimum terms equal to the lesser of (a) the term of the ESA
being requested by the Qualifying Facility in Section 1.a.xiv., or (b) the minimum term required by the
third-party transmission entity to ensure firm roll over transmission rights, and (c) any other applicable
terms and conditions to ensure the Facility shall have firm transmission rights for the full term of the
ESA.

RATE OPTIONS

The Company is required to pay the following rates, at the election of the Qualifying Facility, for
the purchase of output from Facilities for which this tariff applies and that is delivered and accepted by
the Company in accordance with the ESA. These rates are adjusted periodically and are on file with
the Commission.

Idaho Power Company Original Sheet No. 73-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-3

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

RATES OPTIONS (Continued)

1. Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled with
fossil fuels and shall depend upon the on-line operation date and term of the agreement and shall be
fixed for the term. The adjustable component rate shall be changed periodically subject to Commission
orders. Both the fixed and adjustable rate components are subject to Seasonal Factors, a Daily Shape
Adjustment, and Integration Charges.

2. Non-Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Non-Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled
with fossil fuels and shall depend upon the on-line operation date and term of the agreement. The fixed
component rate shall be fixed for the term of the agreement. The adjustable component rate shall be
changed periodically subject to Commission orders. Both the fixed and adjustable rate components are
subject to Seasonal Factors, a Daily Shape Adjustment, and Integration Charges.

3. Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Non-Fueled Facilities. These rates shall apply to Facilities that
do not use fossil fuels as their primary fuel. The rates shall depend upon the on-line operation date and
term of the agreement and shall be fixed for the term. The rate components are subject to Seasonal
Factors, a Daily Shape Adjustment, and Integration Charges.

4. Non-Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects
at or below the Eligibility Cap when the Customer chooses to supply output including energy and
capacity under a contract based on Non-Levelized Avoided Cost Rates for Non-Fueled Facilities.
These rates shall apply to Facilities that do not use fossil fuels as their primary fuel, and shall be fixed
for the term. The rates are subject to a Seasonal Factor, a Daily Shape Adjustment, and Integration
Charges.

5. Rates Determined at the Time of Delivery. Please see the Company’s tariff Schedule
86.

6. Integrated Resource Plan (“IRP”) Based Rate. The IRP Based Rate is required for all
Qualifying Facilities that do not meet the Eligibility Cap and shall be calculated based on the
Incremental Cost IRP Methodology tailored to the individual characteristics of the proposed Qualifying
Facility.

CONTRACTING PROCEDURES

The Company agrees to adhere to the following contract procedures for the purchase of output
from Customers who own Qualifying Facilities for which this tariff applies and that is delivered to the
Company’s system. These contracting procedures are adjusted periodically and are on file with the
Commission.

Idaho Power Company Original Sheet No. 73-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures

a. To obtain an indicative pricing proposal for a proposed Qualifying Facility, the
Customer shall provide the Company a completed Qualifying Facility Energy Sales Agreement
Application utilizing the Application template included in this Schedule. The information required
within the application is general information as listed below.

i. Qualifying Facility owner name, organizational structure and chart, contact
information, and project name;

ii. Generation and other related technology applicable to the Qualifying
Facility;

iii. Maximum design capacity, station service requirements, and the net
amount of power, all in kW, to be delivered to the Company’s electric system by the
Qualifying Facility;

iv. Schedule of estimated Qualifying Facility electric output, in an 8,760-hour
electronic spreadsheet format;

v. Ability, if any, of Qualifying Facility to respond to dispatch orders from the
Company;

vi. Map of Qualifying Facility location, electrical interconnection point, and
POD (identified by nearest landmark and GPS coordinates);

vii. Anticipated commencement date for delivery of electric output;

viii. List of acquired and outstanding Qualifying Facility permits, including a
description of the status and timeline for acquisition of any outstanding permits;

ix. Demonstration of ability to obtain Qualifying Facility status;

x. Fuel type(s) and source(s);

xi. Plans to obtain, or actual fuel and transportation agreements, if
applicable;

xii. Where Qualifying Facility is or will be interconnected to an electrical
system besides the Company’s, plans to obtain, or actual electricity transmission
agreements with the interconnected system;

xiii. Interconnection agreement status; and
Idaho Power Company Original Sheet No. 73-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-5

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

xiv. Proposed contracting term and requested Rate Option for the sale of
electric output to the Company.

b. Where the Company determines that the Customer has not provided sufficient
information as required by Section 1.a., the Company shall, within 10 business days, notify the
Customer in writing of any deficiencies.

c. Following satisfactory receipt of all information required in Section 1.a., the
Company shall, within 20 business days, provide the Customer with an indicative pricing
proposal containing terms and conditions tailored to the individual characteristics of the
proposed Qualifying Facility; provided, however, that for Qualifying Facilities eligible for
Published Rates pursuant to the Commission’s eligibility requirements, the Company will
provide such indicative pricing proposal within 10 business days.

d. The indicative pricing proposal provided to the Customer pursuant to Section 1.c.
will not be final or binding on either party. Prices and other terms and conditions will become
final and binding on the parties under only two conditions:

i. The prices and other terms contained in an ESA shall become final and
binding upon full execution of such ESA by both parties and approval by the
Commission, or

ii. The applicable prices that would apply at the time a complaint is filed by a
Qualifying Facility with the Commission shall be final and binding upon approval of such
prices by the Commission and a final non-appealable determination by the Commission
that:

(a) a “legally enforceable obligation” has arisen and, but for the
conduct of the Company, there would be a contract, and
(b) the Qualifying Facility can deliver its electrical output within 365
days of such determination.

e. If the Customer desires to proceed with contracting its Qualifying Facility with the
Company after reviewing the indicative pricing proposal, it shall request in writing that the
Company prepare a draft ESA to serve as the basis for negotiations between the parties. In
connection with such request, the Customer shall provide the Company with any additional
Qualifying Facility information that the Company reasonably determines necessary for the
preparation of a draft ESA, which shall include:

i. Updated information of the categories described in Section 1.a.

ii. Evidence of site control for the entire contracting term
Idaho Power Company Original Sheet No. 73-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-6

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

iii. Anticipated timelines for completion of key Qualifying Facility milestones,
to include:

(a) Licenses, permits, and other necessary approvals;
(b) Funding;
(c) Qualifying Facility engineering and drawings;
(d) Significant equipment purchases;
(e) Construction agreement(s);
(f) Interconnection agreement(s); and
(g) Signing of third-party Transmission Agreements, where
applicable.

iv. Additional information as explained in the Company’s indicative pricing
proposal.

f. If the Company determines that the Customer has not provided sufficient
information as required by Section 1.e., the Company shall, within 10 business days, notify the
Customer in writing of any deficiency.

g. Following satisfactory receipt of all information required in Section 1.e., the
Company shall, within 15 business days, provide the Customer with a draft ESA containing a
comprehensive set of proposed terms and conditions. The draft shall serve as the basis for
subsequent negotiations between the parties and, unless clearly indicated, shall not be
construed as a binding proposal by the Company.

h. Within 90 calendar days after its receipt of the draft ESA from the Company
pursuant to Section 1.g., the Customer shall review the draft ESA and shall (a) notify the
Company in writing that it accepts the terms and conditions of the draft ESA and is ready to
execute an ESA with same or similar terms and conditions as the draft ESA or (b) prepare an
initial set of written comments and proposals based on the draft and provide them to the
Company. The Company shall not be obligated to commence negotiations with a Customer or
draft a final ESA unless or until the Company has timely received an initial set of written
comments and proposals from the Customer, or notice from the Customer that it has no such
comments or proposals, in accordance with this Section 1.h.

i. After Customer has met the provisions of Section 1.h. above, Customer shall
contact the Company to schedule ESA negotiations at such times and places as are mutually
agreeable to the parties.

Idaho Power Company Original Sheet No. 73-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-7

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

j. In connection with any ESA negotiations between the Company and the
Customer, the Company:

i. Shall not unreasonably delay negotiations and shall respond in good faith
to any additions, deletions, or modifications to the draft ESA that are proposed by the
Customer;

ii. May request to visit the site of the proposed Qualifying Facility;

iii. Shall update its pricing proposals at appropriate intervals to
accommodate any changes to the Company’s avoided cost calculations, the proposed
Qualifying Facility or proposed terms of the draft ESA;

iv. Shall include any revised contracting terms, standards, or requirements
that have occurred since the initial draft ESA was provided;

v. May request any additional information from the Customer necessary to
finalize the terms of the ESA and to satisfy the Company’s due diligence with respect to
the Qualifying Facility.

k. When both parties are in full agreement as to all terms and conditions of the draft
ESA, including the price paid for delivered energy, and the Customer provides evidence that
any applicable Transmission Agreements have been executed and/or execution is imminent, the
Company shall prepare and forward to the Customer, within 10 business days, a final,
executable version of the ESA.

l. The Customer shall, within 10 business days, execute and return the final ESA to
the Company.

m. Where the Customer timely executes and returns the final ESA to the Company
in accordance with Section 1.l. above, the Company will, within 10 business days of its receipt
of the ESA executed by the Customer, execute such ESA. The Company will then submit the
executed ESA to the Commission for its review.

n. Failure of the Customer to meet any timelines set forth in this section relieves the
Company of any obligation under this tariff until such time as the Customer resubmits its
Qualifying Facility and the procedures begin anew. If the Customer does not execute the final
ESA per Section 1.l, such final ESA shall be deemed withdrawn and the Company shall have
no further obligation to the Customer under this tariff unless or until such time the Customer
resubmits the Qualifying Facility to the Company in accordance with this Schedule.

Idaho Power Company Original Sheet No. 73-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-8

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – July 1, 2023 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

2. Interconnection, Transmission Agreements, and Designated Network Resource

a. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the consummation of a GIA in accordance with the
Company’s Schedule 72. Where the Qualifying Facility will not be physically located within the
Company’s electrical system, the Customer will need to consummate a similar GIA with the
third-party electrical system.

b. Where the Qualifying Facility will be interconnected to a third-party electrical
system and is requesting either Published Rates, or rates based on firm delivery of its electrical
output, the Company’s obligation to purchase such electrical output will be conditioned on the
Customer obtaining a firm Transmission Agreement or agreements to deliver all electrical output
to the agreed upon POD.

c. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the Facility being classified as a Company Designated
Network Resource.

3. Qualifying Facility Energy Sales Agreement Application

(FORM STARTS ON NEXT PAGE)
Idaho Power Company First RevisedOriginal Sheet No. 73-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 73-9

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – March 15, 2017 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 April 15, 2017 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION

Idaho Power Qualifying Facility (QF) contact information:

Mailing Address: Attn: Energy Contracts, P O Box 70 Boise, ID 83702
Physical Address: 1221 W. Idaho Street, Boise, ID 83703
Telephone number: 208-388-6070
E-Mail Address: [e-mail]

Preamble and Instructions

All generation facilities that qualify pursuant to Idaho Power Company Schedule 73 for a QF Energy
Sales Agreement and wish to sell energy from their facility to Idaho Power must complete the following
information and submit this Application by hand delivery, mail or E-mail to Idaho Power.

Upon receipt of a complete Application, Idaho Power shall process this request for a QF Energy Sales
Agreement pursuant to Idaho Power Company Schedule 73.

Qualifying Facility Information

Proposed Project
Name of Facility:
Resource Type: (i.e. wind, solar, hydro, etc):
Facility Location: GPS Coordinates:
Nearest City or landmark:
County and State:
Map of Facility, including proposed interconnection point.
Anticipated commencement date of energy deliveries to Idaho Power:
Facility Nameplate Capacity Rating (kW):
Facility Maximum Output Capacity (kW):
Station Service Requirements (kW):
Facility Net Delivery to Idaho Power (kW):
Facility interconnection status:
Proposed Contracting Term (cannot exceed 20 years):
Requested Rate Option (details provided in Schedule 73):
Does the Facility have the ability to respond to dispatch
orders from Idaho Power Company (Yes or No):

Idaho Power Company Original Sheet No. 73-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 73-10

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION
(Continued)

Please include the following attachments:

 Hourly estimated energy deliveries (kW) to Idaho Power for every hour of a one year period.

 List of acquired and outstanding Qualifying Facility permits, including a description of the status
and timeline for acquisition of any outstanding permits.
 At the minimum a FERC issued QF certificate/self-certification is required and/or
evidence that Facility will be able to obtain a Qualifying Facility certificate.

 If the Facility will require fuel be transported to the Facility (i.e. natural gas pipelines, railroad
transportation, etc), evidence of ability to obtain sufficient transportation rights to operate the
Facility at the stated Maximum Output Amount.

 If the Facility will not be interconnecting directly to the Idaho Power electrical system, evidence
that the Facility will be able to interconnect to another utility’s electrical system and evidence
that the Facility will be able to obtain firm transmission rights over all required transmission
providers to deliver the Facility’s energy to Idaho Power.

Owner Information
Owner / Company Name:
Contact Person:
Address:
City: State: Zip:
Telephone:
E-mail:

Applicant Signature

I hereby certify that, to the best of my knowledge, all information provided in this Qualifying
Facility Energy Sales Agreement application is true and correct.

__________________________________________________________________
Signature

__________________________________________________________________
Print Name

________________________________________
Date
Idaho Power Company First RevisedOriginal Sheet No. 79-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101First RevisedOriginal Sheet No. 79-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.35583 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 November 4, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 79
WEATHERIZATION ASSISTANCE
FOR QUALIFIED CUSTOMERS

AVAILABILITY

Funding under this schedule is available to state designated Community Action Partnership
(CAP) agencies throughout the Company's service area within the State of Idaho participating in the
State of Idaho Weatherization Assistance Program administered by the Idaho Department of Health
and Welfare. Funding under this schedule is subject to the provisions of the signed Agreement
between the individual CAP agencies and the Company.

APPLICABILITY

Funding under this schedule is applicable to qualifying energy conservation measures installed
in single- and multi-family residential dwellings, including mobile homes, which are electrically heated
(Qualifying Dwellings). Funding is also applicable to qualifying energy conservation measures installed
in buildings which are occupied by private, non-profit organizations which serve primarily low-income
clientele, and which have obtained a 501(c)(3) tax exempt status (Qualifying Buildings). Energy
conservation measures installed in Qualifying Dwellings and Qualifying Buildings must meet the
specifications of the State of Idaho Weatherization Assistance Program.

GRANTS TO AGENCIES

The Company will determine the amount of annual grant funds available to each participating
CAP agency each year in accordance with the provisions of the Agreement. Funds will be distributed
to a participating CAP agency upon demonstration by the agency that qualifying conservation
measures have been installed in a Qualifying Dwelling or Qualifying Building. Grant funds made
available to a CAP agency but not distributed to that agency during the current year may be carried
forward to the next year.

In addition to weatherization funds, the Company will provide to each CAP agency an
administrative payment equal to 10 percent of the portion funded by the Company for each Qualifying
Dwelling or Qualifying Building for which weatherization was completed with the assistance of
Company funds.

Qualifying Dwellings: The Company grant funds may be used to fund up to 85 percent of the
total cost of qualifying conservation measures installed in a Qualifying Dwelling provided at least 15
percent of the total cost of qualifying conservation measures is funded by the Department of Energy,
except in the case where carryover funds are being used for re-weatherization. Re-weatherization
applies to homes that were previously weatherized under Schedule 79 within a rolling 14-year period.
For those homes, the program’s carryover funds may be used to pay up to 100 percent of HVAC
upgrades.

Qualifying Buildings: The Company grant funds may be used to fund the installation of
weatherization measures in Qualifying Buildings in accordance with the provisions of the Agreement.
The Company provided funds may be used to fund up to 100 percent of the total cost of qualifying
conservation measures installed in Qualifying Buildings.

Idaho Power Company Third RevisedOriginal Sheet No. 81-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 81-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)

PURPOSE

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

DEFINITIONS

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

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

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

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

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

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

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

Idaho Power Company Fourth RevisedOriginal Sheet No. 81-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 81-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2018 1221 West Idaho Street, Boise, Idaho

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

AVAILABILITY

Service under this schedule is available on an optional basis to Customers taking service under
Schedules 1, 5, or 6 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 Idaho 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. If 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.

Idaho Power Company Third RevisedOriginal Sheet No. 81-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Second Third Revised Sheet No. 81-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35336 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 4, 2022 1221 West Idaho Street, Boise, Idaho

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

PROGRAM DESCRIPTION

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

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

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

SPECIAL CONDITIONS

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

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

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

The provisions of this schedule do not apply for any time period that the Company interrupts the
Customer’s load for a system emergency in accordance with NERC standards, Idaho Power’s Rule J,
or any other time that a Customer’s service is interrupted by events outside the control of the Company.
The provisions of this schedule will not affect the calculation or rate of the regular Service or Energy
Charges associated with a Customer’s standard service schedule.
Idaho Power Company Third RevisedOriginal Sheet No. 82-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 82-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

PURPOSE

The Flex Peak Program (the Program) is a voluntary program that motivates Participants to
reduce their load during Company initiated Load Control Events or to allow the Company to send a signal
to automatically initiate a Load Control Event with the use of one or more Load Control Devices. A
participating Customer will be eligible to receive a financial incentive in exchange for being available to
reduce their load during the calendar months of June, July, August, and September.

AVAILABILITY

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

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

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

PROGRAM DESCRIPTION

The Company will initiate Load Control Events for a maximum of 60 hours during June, July,
August, and September. During Load Control Events, Participants will be expected to reduce load at their
Facility Site(s), and load reduction may be initiated manually or automatically depending on the
Interruption Option designated for the Facility Site(s). Participants will be eligible to receive a financial
incentive in exchange for their reduction in load.

DEFINITIONS

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

Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment
amount.
Idaho Power Company Second RevisedOriginal Sheet No. 82-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 82-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

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

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

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

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

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

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

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

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

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

Idaho Power Company Second RevisedOriginal Sheet No. 82-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 82-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

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

Notification of Program Acceptance. Written confirmation from the Company to the Participant
based on the Program Application Agreement submitted by the Customer. The Notification of Program
Acceptance will confirm each Facility Site enrolled in the Program, the initial Nominated kW amount for
each Facility Site, and the Interruption Option for each Facility Site.

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

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

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

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

Original 
Baseline 
(kW) 3367 3400 3350 3367 3433 3400 

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

Program Application/Agreement. Written form submitted by a Customer who requests to enroll
a Facility Site in the Program that is signed by the Customer or a duly authorized representative
certifying agreement with the Program’s terms and conditions.

Idaho Power Company Third RevisedOriginal Sheet No. 82-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Second Third Revised Sheet No. 82-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

DEFINITIONS (Continued)

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

Program Week. Monday through Friday.

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

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

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

LOAD CONTROL EVENTS

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

INTERRUPTION OPTIONS

At the Participant’s election, and subject to Company discretion, participation in the Program may
occur via one of the following Interruption Options:

Manual Dispatch Option. Customers are eligible to manually control their Facility Site(s). Under
the Manual Dispatch Option customers have the flexibility to choose which loads will be interrupted during
each dispatched Load Control Event.

Automatic Dispatch Option. A dispatchable Load Control Device, provided and installed by the
Company or its representative, will be connected to the electrical panel(s) serving the loads associated
with the Facility Site(s) enrolled in the Program. The Load Control Device utilized under the Automatic
Dispatch Option will provide the Company the ability to send a signal intended to interrupt operation of a
particular load or service during dispatched Load Control Events. In lieu of the Company or its
representative installing the Load Control Device at the Company’s expense, the Participant may elect
to hire a licensed electrician, at the Participant’s expense, to install the Load Control Device in accordance
Idaho Power Company Third RevisedOriginal Sheet No. 82-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 82-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

INTERRUPTION OPTIONS (Continued)

with the National Electrical Code (“NEC”) and any Idaho Power or manufacturer specifications or
requirements.

REQUIREMENTS OF PARTICIPATING FACILITIES

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

INCENTIVE STRUCTURE

Incentive payments will be determined based on a Fixed Capacity Payment, a Variable Energy
Payment, and any applicable Nominated kW Incentive Adjustment. Both the Fixed Capacity and Variable
Energy Payments will be paid by check or bill credit no more than 45 days after the Program Season
concludes on September 15th.

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

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

For Load Control Events, the Nominated kW Incentive Adjustment will be $2.00 per kW for each
hour the Nominated kW is not achieved during that interval. The total Nominated kW Incentive
Adjustments will not exceed the total incentive amount for the Program Season. At its discretion, the
Company may waive all or a portion of an Incentive Adjustment should it be determined that, at no fault
of the customer, the Load Control Device utilized for the Automatic Dispatch Option did not work during
a Load Control Event.

Fixed Capacity Payment Rate*
(*to be prorated for partial weeks) Variable Energy Payment Rate*
(*does not apply to first four Load Control Events)

$3.25 per Weekly Effective kW Reduction

$0.20 per kWh
Idaho Power Company Original Sheet No. 82-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 82-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

TERMS AND CONDITIONS

Upon acceptance into the Program, Participants agree to the provisions of this Schedule and to
the following terms and conditions:

1. Once accepted into the Program, Participants will automatically be re-enrolled each year
thereafter unless notice of termination is given by the other party.

2. Both the Company and the Participant may terminate participation in the Program
at any time by notifying the other party in writing.

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

4. The Company retains the sole right to determine the criteria under which a Load Control
Event is called and the decision of whether to call for, initiate, or cancel a Load Control
Event shall be at the Company’s sole discretion.

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

6. Participants that choose to participate in the Program under the Automatic Dispatch
Option grant the Company or its representative permission, on reasonable notice, to enter
the Customer’s enrolled Facility Site(s) to install, service, maintain, and/or remove Load
Control Device(s) on the electrical panel that services the anticipated load reduction. The
Company retains the sole right for its employees and its representatives to install or not
install Load Control Devices on the Customer’s electrical panel at the time of installation
depending on, but not limited to, safety, reliability, or other issues that may not be in the
best interest of the Company, its employees, or its representatives.

7. If there is evidence of the Participant altering, tampering, or otherwise interfering with the
Company’s ability to initiate a Load Control Event, the Customer’s participation in the
Program will be terminated, and the Customer will be required to reimburse the Company
for all costs for replacement or repair of the Load Control Device(s) or other Program
equipment, including labor and other related costs, and the Company will reverse any and
all incentive payments made during the previous twelve months as a result of the
Customer’s participation in the Program.

Idaho Power Company Original Sheet No. 82-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 82-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35677 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 3, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 82
FLEX PEAK
PROGRAM
(OPTIONAL)

SPECIAL CONDITIONS

The Company is not responsible for any direct, indirect, consequential, incidental, punitive, or
exemplary damage to the Participant or third parties as a result of the Program or the Customer’s
voluntary participation in the Program.

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

The provisions of this Program do not apply for any time period that the Company requests a load
reduction during a system emergency in accordance with NERC standards, Idaho Power’s Rule J, or any
other time that a Customer’s service is interrupted by events outside the control of the Company. The
provisions of this Program will not affect the calculation or rate of the regular Service, Energy, or Demand
Charges associated with a Participant’s standard service schedule.
Idaho Power Company Sixth RevisedOriginal Sheet No. 84-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Fifth Sixth Revised Sheet No. 84-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company’s service territory area within the
State of Idaho for Customers intending to operate Exporting Systems to generate electricity to reduce all
or part of their monthly energy usage.

Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small
general service customers.

Effective December 2, 2020, Schedule 84 is closed to new applications with a two-meter
interconnection.

APPLICABILITY

Service under this schedule is applicable to any Customer that:

1. Does not take service under Schedule 4, Schedule 5, Schedule 6, or Schedule 8; and

2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal,
or hydropower, or represents fuel cell technology; and

3. Maintains its retail electric service account for the loads served at the Point of Delivery
adjacent to the Generation Interconnection Point as active and in good standing; and

4. Meets all requirements applicable to Exporting Systems detailed in the Company’s
Schedule 68, Interconnections to Customer Distributed Energy Resources; and

5. Takes retail electric service under:

a. Schedule 1 or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25
kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the
Company is through the Company’s existing watt-hour retail meter.

b. Schedule 9, Schedule 19, or Schedule 24; and

i. Two Meter Interconnection (Closed to new applicants effective December
2, 2020): Owns and/or operates a Generation Facility with a total nameplate capacity
rating of 100 kW or smaller that is interconnected at a Generation Interconnection Point
that, at the Company’s discretion, is located either adjacent to or on the Customer’s side
of the Point of Delivery and is metered through a meter that is separate from the retail
load metering at the Customer’s Point of Delivery. A separate meter from the existing
retail load metering at the Customer’s Point of Delivery is not required if the Customer
meets the criteria below. The One Meter Option is available if:

Idaho Power Company Third RevisedOriginal Sheet No. 84-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 84-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34892 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 14, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

APPLICABILITY (Continued)

1. The Generation Facility has a total nameplate capacity rating of 25
kW or smaller; and

2. The Generation Facility has a total nameplate capacity rating that
is no more than 2% of the Customer’s Basic Load Capacity (BLC) or comparable
average maximum monthly Billing Demands.

ii. Single-Meter Interconnection (applicable to new applicants effective
December 2, 2020): Owns and/or operates a Generation Facility with a total nameplate
rating of 100 kW or smaller that is interconnected to the Customer’s individual electric
system on the Customer’s side of the Point of Delivery, thus all energy received and
delivered by the Company is through the Company’s existing watt-hour retail meter.

6. A Customer submitting a two-meter interconnection application for service under
Schedule 84 must complete the interconnection pursuant to the terms of Schedule 72 by December 1,
2021. Grandfather Status will terminate on December 1, 2045.

7. The Grandfather Status of the two-meter Generation Facility is transferable to a
subsequent Customer at the premises for which a valid Net Metering Service is in effect. Each
Customer of a Generation Facility taking service under Schedule 84 will be responsible for complying
with the terms and conditions of the Net Metering Service in effect for that premises.

8. A two-meter Generation Facility that is offline for over six (6) months or that is moved to
a different site shall forfeit Grandfather Status of the Generation Facility.

9. To remain eligible for Grandfather Status, a Customer may increase the capacity of a
grandfathered Generation Facility by no more than 10 percent of the originally installed nameplate
capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded
components. If a Customer expands a grandfathered Generation Facility beyond these limits, the new
portion of the Generation Facility would not qualify for Grandfather Status.

10. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the
Grandfathered Status of the Generation Facility.

Idaho Power Company Fourth RevisedOriginal Sheet No. 84-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 84-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

DEFINITIONS

Basic Load Capacity (BLC) is the average of the two greatest non-zero monthly Billing Demands
established during the 12-month period which includes and ends with the current Billing Period.

Designated Meter is the retail meter physically connected to the Exporting System.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company. An Exporting System is
interconnected to the Company’s system under the applicable terms of Schedule 68.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is either delivered to the Company via a single meter at the Point of Delivery or Generation
Interconnection Point, or is consumed by the Customer.

Generation Interconnection Point is the point where the conductors installed to allow receipt of the
Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery.

Grandfathered Status refers to the ability for a system to receive the compensation structure in
place on December 1, 2020. The compensation structure applicable to systems with a Grandfather
Status includes net monthly one-for-one kWh credit compensation for Excess Net Energy.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery or Generation Interconnection Point.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 68 is the Company’s service schedule which provides for interconnection to customer
generation or its successor schedule(s) as approved by the Commission.

Idaho Power Company Fourth RevisedOriginal Sheet No. 84-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 84-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

MONTHLY BILLING

The Customer shall be billed in accordance with the Customer’s applicable standard service
schedule, including appropriate monthly charges.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period,
the Customer shall be billed for the net electricity supplied by the Company at the Customer’s
standard schedule retail rate, in accordance with normal metering practices.

b. Effective at the beginning of each Customer’s January 2014 Billing Period, if
electricity generated by the Customer and delivered to the Company during the Billing Period
exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy
shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period.
Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers
shall be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Exporting System. Any
unused credits will expire at the time the final bill is prepared.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end
of the Customer’s December Billing Period the Customer may request to transfer the unused
credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it
meets all of the following criteria:

i. The account subject to offset is held by the Customer; and

Idaho Power Company Second RevisedOriginal Sheet No. 84-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101First Second Revised Sheet No. 84-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

iii. The meter is served by the same primary feeder as the Designated Meter
at the time the Customer files the application for the Exporting System; and

iv. The electricity recorded by the meter is for the Customer’s requirements;
and

v. For Customers taking service under Schedule 1 or Schedule 7, credits may
only be transferred to meters taking service under Schedule 1 or Schedule 7. For
Customers taking service under Schedule 9, Schedule 19, or Schedule 24, credits may
only be transferred to meters taking service under Schedule 9, Schedule 19, or Schedule
24.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by
midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer
Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will
carry forward to offset consumption at the Designated Meter until they become eligible for transfer
on January 1 of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the
Company no later than March 31. Transfers will be based on the balance of Excess Net Energy
credits available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v)
above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any
reason.

Idaho Power Company First RevisedOriginal Sheet No. 84-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 84-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 23, 2021 January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of a Exporting System to the Company’s system, or for the acts or omissions of the
Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of
electricity in the same manner and to the same degree as other Customers on the Company’s standard
service schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the
purpose of installation, operation, maintenance, replacement or any other service required of said
equipment, as well as all necessary access for inspection, switching and any other operational
requirements of the Customer’s Interconnection Facilities.

9. The Customer shall notify the Company immediately if an Exporting System is
permanently removed or disabled. Permanent removal or disablement for the purposes of this
schedule is any removal or disablement of an Exporting System lasting longer than six (6) months.
Customers with permanently removed systems will be removed from service under this schedule and
placed on the appropriate standard service schedule.

Idaho Power Company First RevisedOriginal Sheet No. 86-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 86-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33053 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 10, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

AVAILABILITY

Service under this schedule is available throughout the Company's service territory area within the
State of Idaho.

APPLICABILITY

Service under this schedule is applicable to any Seller that:

1. Owns or operates a Qualifying Facility with a nameplate capacity rating of less than 10
MW and desires to sell Energy generated by the Qualifying Facility to the Company on a non-firm, if, as,
and when available basis;

2. Meets all applicable requirements of the Company’s Schedule 72 and the Generation
Interconnection Process.

DEFINITIONS

Avoided Energy Cost is 82.4% of the monthly arithmetic average of each day’s Intercontinental
Exchange (“ICE”) daily firm Mid-C Peak Avg and Mid-C Off-Peak Avg index prices. Each day’s index
prices will reflect the relative proportions of peak hours and off-peak hours in the month as follows:

Heavy Load (HL) Hours: The daily hours from hour ending 0700-2200 Mountain
Time, (16 hours) excluding all hours on all Sundays, New Years Day, Memorial
Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.

Light Load (LL) Hours: The daily hours from hour ending 2300-0600 Mountain
Time (8 hours), plus all other hours on all Sundays, New Years Day, Memorial
Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.
The actual Avoided Energy Cost calculation being:
n
.824 * ( ∑ {(ICE Mid-C Peak Avgx * HL hours for day) + X=1
(ICE Mid-C Off-Peak Avgx * LL hours for day)} / (n*24))
where n = number of days in the month

If the ICE Mid-C Index prices are not reported for a particular day or days, prices derived from the
respective averages of HL and LL prices for the immediately preceding and following reporting periods or
days shall be substituted into the formula stated in this definition and shall therefore be multiplied by the
appropriate respective numbers of HL and LL Hours for such particular day or days with the result that
each hour in such month shall have a related price in such formula. If the day for which prices are not
reported has in it only LL Hours (for example a Sunday), the respective averages shall use only prices
reported for LL hours in the immediately preceding and following reporting periods or days. If the day for
which prices are not reported is a Saturday or Monday or is adjacent on the calendar to a holiday, the
prices used for HL Hours shall be those for HL hours in the nearest (forward or backward) reporting
periods or days for which HL prices are reported.
Idaho Power Company First RevisedOriginal Sheet No. 86-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 86-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33053 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 10, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

DEFINITIONS (Continued)

Designated Dispatch Facility is the Company's Boise Bench Dispatch Center.

Energy means the non-firm electric energy, expressed in kWh, generated by the Qualifying
Facility and delivered by the Seller to the Company in accordance with the conditions of this schedule.
Energy is measured net of Losses and Station Use.

Generation Facility means equipment used to produce electric energy at a specific physical
location, which meets the requirements to be a Qualifying Facility.

Generation Interconnection Process is the Company’s generation interconnection application and
engineering review process developed to ensure a safe and reliable generation interconnection.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the National Electric Safety Code to interconnect and safely deliver Energy from the Qualifying Facility to
the Company's system, including, but not limited to, connection, transformation, switching, metering,
relaying, communications, disconnection, and safety equipment.

Losses are the loss of electric energy occurring as a result of the transformation and transmission
of electric energy from the Qualifying Facility to the Point of Delivery.

Point of Delivery is the location where the Company's and the Seller's electrical facilities are inter-
connected.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of the
Code of Federal Regulations.

Schedule 72 is the Company's service schedule which provides for interconnection to non-utility
generation or its successor schedule(s) as approved by the Commission.

Seller is any entity that owns or operates a Qualifying Facility and desires to sell Energy to the
Company.

Idaho Power Company First RevisedOriginal Sheet No. 86-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 86-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33053 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 10, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

DEFINITIONS (Continued)

Standby Power is electrical energy or capacity supplied by the Company during an unscheduled
outage of a Qualifying Facility to replace energy consumed by the seller which is ordinarily supplied by
the Seller's Qualifying Facility.

Station Use is electric energy used to operate the Qualifying Facility which is auxiliary to or directly
related to the generation of electricity and which, but for the generation of electricity, would not be
consumed by the Seller.

Supplementary Power is electric energy or capacity supplied by the Company which is regularly
used by a Seller in addition to the Energy and capacity which the Qualifying Facility usually supplies to
the Seller.

PURCHASE PRICE

The Company will pay the Seller monthly, for each kWh of Energy delivered and accepted at the
Point of Delivery during the preceding calendar month, an amount equal to 85 percent of the monthly
Avoided Energy Cost.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. The Company shall purchase Energy from any Seller that offers to sell Energy to the
Company.

2. As a condition of interconnection with the Company, the Seller shall:

a. Complete and maintain all requirements of interconnection in accordance with
Schedule 72.

b. Complete and maintain all requirements of the Company’s Generation
Interconnection Process.

c. Submit proof to the Company of all insurance required by paragraph 12.

d. Obtain written confirmation from the Company that all conditions to
interconnection have been fulfilled prior to operation of the Generation Facility. Such
confirmation shall not be unreasonably withheld by the Company.

Idaho Power Company First RevisedOriginal Sheet No. 86-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 86-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33053 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 10, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

3. The Seller shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Seller’s Generation Facility is de-energized for any reason.

4. The Seller and the Company shall each indemnify the other, their respective officers,
agents, and employees against all loss, damage, expense, and liability to third persons for injury to or
death of persons or injury to property, proximately caused by the indemnifying party's construction,
ownership, operation or maintenance of, or by failure of, any of such party's works or facilities used in
connection with purchases under this schedule. The indemnifying party shall, on the other party's
request, defend any suit asserting a claim covered by this indemnity. The indemnifying party shall pay
all costs that may be incurred by the other party in enforcing this indemnity.

5. The Company shall offer to provide Standby Power and Supplementary Power to the
Seller. Charges for Supplementary and Standby Power will be in accordance with the Company's
Schedule 7 as that schedule is modified from time to time by the Commission.

6. The Seller shall maintain voltage levels acceptable to the Company.

7. The Seller shall maintain at the Qualifying Facility or such other location mutually
acceptable to the Company and Seller, adequate metering and related power production records, in a
form and content recommended by the Company.

Either the Seller or the Company after reasonable notice to the other party, shall have the right,
during normal business hours, to inspect and audit any or all such metering and related power
production records pertaining to the Seller’s account.

8. During a period of shortage of energy on the Company's system, the Seller shall, at the
Company's request and within the limits of reasonable safety requirements as determined by the Seller,
use its best efforts to provide requested Energy, and shall, if necessary, delay any scheduled shutdown
of the Qualifying Facility.

9. The Company and the Seller shall maintain appropriate operating communications
through the Designated Dispatch Facility.

10. The Company shall not be obligated to accept, and the Company may require the Seller
to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent Electrical
Practices, determines that curtailment, interruption or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.

Idaho Power Company First RevisedOriginal Sheet No. 86-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 86-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33053 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 10, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

11. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its Customers, the Company may require the Seller to curtail its consumption of electricity
in the same manner and to the same degree as other Customers within the same Customer class who
do not own Generation Facilities.

12. The Seller shall secure and continuously carry liability insurance coverage for both
bodily injury and property damage liability in the amount of not less than $1,000,000 each occurrence
combined single limit.

Such insurance shall include an endorsement naming the Company as an additional insured
insofar as liability arising out of operations under this schedule and a provision that such liability policies
shall not be canceled or their limits of liability reduced without 30 days' written notice to the Company.
The Seller shall furnish the Company with certificates of insurance together with the endorsements
required herein. The Company shall have the right to inspect the original policies of such insurance.

13. The Seller shall grant to the Company all necessary rights of way and easements to
install, operate, maintain, replace, and remove the Company's metering and other Interconnection
Facilities including adequate and continuing access rights to the property of the Seller. The Seller
warrants that it has procured sufficient easements and rights of way from third parties as are necessary
to provide the Company with the access described above. The Seller shall execute such other grants,
deeds, or documents as the Company may require to enable it to record such rights of way and
easements.

14. Depending on the size and location of the Seller's Qualifying Facility, it may be
necessary for the Company to establish additional requirements for operation of the Qualifying Facility.
These requirements may include, but are not limited to, voltage, reactive, or operating requirements.

Idaho Power Company Original Sheet
No. 86-6
Cancels
I.P.U.C. No. 29 30, Tariff No. 101 Original Sheet No. 86-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

Idaho Power Company
For the Purchase of Non-Firm
Energy From Qualifying Facilities

THIS AGREEMENT Made this day of , 20 ,
between _______________________________________________________whose mailing address is
______________________________hereinafter called Seller and Idaho Power Company, a corporation
with its principal office located at 1221 West Idaho Street, Boise, Idaho hereinafter called "Company".

NOW, THEREFORE, The parties agree as follows:

1. Company shall purchase Energy produced by the Seller's Qualifying Facility located at or
near, ___________________County of , State of Idaho, located in the
_________ of Section ________, Township, _______ Range , BM, in the form of three phase
60 Hz and at a nominal phase to phase potential of volts, subject to emergency operating
conditions of the Company. Purchases under this Agreement are subject to the Company's applicable
Tariff provisions, including but not limited to Schedules 86 and 72 approved by and as may be hereafter
modified by the Idaho Public Utilities Commission ("Commission") and the provisions of this Agreement.

2. Seller shall pay Company for all costs of Interconnection Facilities as provided for in
Exhibit A of this Agreement and Schedule 72.

3. In addition to the charges provided under Paragraph 2, Seller shall pay to the Company
the monthly Operation & Maintenance Charge specified in Schedule 72 on the investment by the
Company in Interconnection Facilities which investment is set forth in Exhibit A, attached hereto and
made a part hereof. As such investment changes, in order to provide facilities to serve Seller’s
requirements, Company shall notify Seller in writing of additions or deletions of facilities by forwarding a
dated revised Exhibit A, which shall become part of this Agreement. The monthly Operation &
Maintenance Charge will be adjusted to correspond to the Revised Exhibit A.

4. The initial date of acceptance of Energy under this Agreement is subject to the Company's
ability to obtain required labor, materials, equipment, satisfactory rights of way, and comply with
governmental regulations.

5. The term of this Agreement shall become effective on the date first above written, and
shall continue to full force and effect until canceled by Seller upon sixty (60) days prior written notice.

6. 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 Commission and such other
administrative bodies having jurisdiction.

Idaho Power Company Original Sheet No. 86-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 86-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 30508 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 March 1, 2008 1221 West Idaho Street, Boise, Idaho

SCHEDULE 86
COGENERATION AND SMALL
POWER PRODUCTION NON-FIRM
ENERGY

Idaho Power Company
For the Purchase of Non-Firm
Energy From Qualifying Facilities
(Continued)

7. Nothing herein shall be construed as limiting the Commission from changing any rates,
charges, classification or service, or any rules, regulation or conditions relating to service under this
Agreement, or construed as affecting the right of the Company or the Seller to unilaterally make
application to the Commission for any such change.

8. This Agreement shall not become effective until the Commission approves all terms and
provisions hereof without change or condition and declares that all payments to be made hereunder
shall be allowed as prudently incurred expenses for rate making purposes.

(APPROPRIATE SIGNATURES)

Idaho Power Company First RevisedOriginal Sheet No. 87-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES

APPLICABILITY

This schedule is applicable to all qualifying facility (“QF”) generators interconnected to the
Company that have generation of an intermittent nature, such as wind and solar generation. The initial
charges within this schedule are to be assessed to intermittent generation based upon the total
nameplate capacity of a specific type of intermittent generation interconnected to Company’s system.

The appropriate charges within this schedule will be included in all QF contracts, both published
and negotiated, at the time those contracts are executed and, once added, shall remain unchanged in
the contract for its duration. Subsequent changes to the charges within this schedule will only apply to
new QF contracts at the time those contracts are executed.

PART 1 – WIND INTEGRATION CHARGES

The following tables are applicable to all QF wind generation contracts that come online after
October 10, 2014:

Continued on next page
Idaho Power Company Original Sheet No. 87-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

601 - 700 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 14.94 2014 11.99
2015 15.39 2015 12.35
2016 15.85 2016 12.72
2017 16.33 2017 13.10
2018 16.82 2018 13.50
2019 17.32 2019 13.90
2020 14.32
2021 14.75
2022 15.19
2023 15.65
2024 16.12
2025 16.60
2026 17.10
2027 17.61
2028 18.14
2029 18.68
2030 19.24
2031 19.82
2032 20.42
2033 21.03
2034 21.66
2035 22.31
2036 22.98
2037 23.67
2038 24.38
2039 25.11

Idaho Power Company Original Sheet No. 87-3
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

701 - 800 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 19.38 2014 15.55
2015 19.96 2015 16.02
2016 20.56 2016 16.50
2017 21.17 2017 17.00
2018 21.81 2018 17.51
2019 22.46 2019 18.03
2020 18.57
2021 19.13
2022 19.70
2023 20.29
2024 20.90
2025 21.53
2026 22.18
2027 22.84
2028 23.53
2029 24.23
2030 24.96
2031 25.71
2032 26.48
2033 27.27
2034 28.09
2035 28.93
2036 29.80
2037 30.70
2038 31.62
2039 32.57

Idaho Power Company Original Sheet No. 87-4
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

801 - 900 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 24.34 2014 19.54
2015 25.07 2015 20.13
2016 25.83 2016 20.73
2017 26.60 2017 21.35
2018 27.40 2018 21.99
2019 28.22 2019 22.65
2020 23.33
2021 24.03
2022 24.75
2023 25.50
2024 26.26
2025 27.05
2026 27.86
2027 28.70
2028 29.56
2029 30.44
2030 31.36
2031 32.30
2032 33.27
2033 34.26
2034 35.29
2035 36.35
2036 37.44
2037 38.56
2038 39.72
2039 40.91

Idaho Power Company Original Sheet No. 87-5
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

901 - 1000 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 29.82 2014 23.94
2015 30.72 2015 24.66
2016 31.64 2016 25.40
2017 32.59 2017 26.16
2018 33.57 2018 26.94
2019 34.57 2019 27.75
2020 28.59
2021 29.44
2022 30.33
2023 31.24
2024 32.17
2025 33.14
2026 34.13
2027 35.16
2028 36.21
2029 37.30
2030 38.42
2031 39.57
2032 40.76
2033 41.98
2034 43.24
2035 44.54
2036 45.87
2037 47.25
2038 48.66
2039 50.12

Idaho Power Company Original Sheet No. 87-6
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

1001 - 1100 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 35.81 2014 28.74
2015 36.88 2015 29.60
2016 37.99 2016 30.49
2017 39.13 2017 31.41
2018 40.30 2018 32.35
2019 41.51 2019 33.32
2020 34.32
2021 35.35
2022 36.41
2023 37.50
2024 38.63
2025 39.78
2026 40.98
2027 42.21
2028 43.47
2029 44.78
2030 46.12
2031 47.51
2032 48.93
2033 50.40
2034 51.91
2035 53.47
2036 55.07
2037 56.72
2038 58.43
2039 60.18

Idaho Power Company Original Sheet No. 87-7
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

WIND INTEGRATION CHARGES (Continued)

1101 - 1200 MW Wind Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
CONTRACT
YEAR
NON-
LEVELIZED
RATES

2014 42.27 2014 33.93
2015 43.54 2015 34.95
2016 44.85 2016 36.00
2017 46.19 2017 37.08
2018 47.58 2018 38.19
2019 49.01 2019 39.34
2020 40.52
2021 41.73
2022 42.98
2023 44.27
2024 45.60
2025 46.97
2026 48.38
2027 49.83
2028 51.33
2029 52.87
2030 54.45
2031 56.09
2032 57.77
2033 59.50
2034 61.29
2035 63.12
2036 65.02
2037 66.97
2038 68.98
2039 71.05

Idaho Power Company First RevisedOriginal Sheet No. 87-8
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33227 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 February 11, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

PART 2 – SOLAR INTEGRATION CHARGES

The following tables are applicable to all QF solar generation contracts that come online after February
11, 2015:

Continued on next page

Idaho Power Company First RevisedOriginal Sheet No. 87-9
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

0 - 100 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.04 2016 0.04
2017 0.04 2017 0.04
2018 0.04 2018 0.04
2019 0.05 2019 0.04
2020 0.05 2020 0.04
2021 0.05 2021 0.04
2022 0.04
2023 0.04
2024 0.04
2025 0.04
2026 0.04
2027 0.05
2028 0.05
2029 0.05
2030 0.05
2031 0.05
2032 0.05
2033 0.05
2034 0.05
2035 0.05
2036 0.06
2037 0.06
2038 0.06
2039 0.06
2040 0.06
2041 0.06

Idaho Power Company First RevisedOriginal Sheet No. 87-10
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

101 - 200 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.19 2016 0.16
2017 0.20 2017 0.17
2018 0.20 2018 0.17
2019 0.21 2019 0.18
2020 0.21 2020 0.18
2021 0.22 2021 0.18
2022 0.19
2023 0.19
2024 0.20
2025 0.20
2026 0.20
2027 0.21
2028 0.21
2029 0.22
2030 0.22
2031 0.23
2032 0.23
2033 0.24
2034 0.24
2035 0.25
2036 0.25
2037 0.26
2038 0.27
2039 0.27
2040 0.28
2041 0.28

Idaho Power Company First RevisedOriginal Sheet No. 87-11
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

201 - 300 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.41 2016 0.34
2017 0.42 2017 0.35
2018 0.43 2018 0.36
2019 0.44 2019 0.37
2020 0.44 2020 0.38
2021 0.45 2021 0.38
2022 0.39
2023 0.40
2024 0.41
2025 0.42
2026 0.43
2027 0.44
2028 0.45
2029 0.46
2030 0.47
2031 0.48
2032 0.49
2033 0.50
2034 0.51
2035 0.52
2036 0.53
2037 0.54
2038 0.56
2039 0.57
2040 0.58
2041 0.59

Idaho Power Company First RevisedOriginal Sheet No. 87-12
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

301 - 400 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED

ON-LINE
YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.64 2016 0.54
2017 0.65 2017 0.55
2018 0.67 2018 0.56
2019 0.68 2019 0.57
2020 0.70 2020 0.59
2021 0.71 2021 0.60
2022 0.61
2023 0.63
2024 0.64
2025 0.66
2026 0.67
2027 0.68
2028 0.70
2029 0.71
2030 0.73
2031 0.75
2032 0.76
2033 0.78
2034 0.80
2035 0.81
2036 0.83
2037 0.85
2038 0.87
2039 0.89
2040 0.91
2041 0.93

Idaho Power Company First RevisedOriginal Sheet No. 87-13
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

401 - 500 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 0.84 2016 0.71
2017 0.86 2017 0.73
2018 0.88 2018 0.75
2019 0.90 2019 0.76
2020 0.92 2020 0.78
2021 0.94 2021 0.80
2022 0.81
2023 0.83
2024 0.85
2025 0.87
2026 0.89
2027 0.91
2028 0.93
2029 0.95
2030 0.97
2031 0.99
2032 1.01
2033 1.03
2034 1.06
2035 1.08
2036 1.10
2037 1.13
2038 1.15
2039 1.18
2040 1.20
2041 1.23

Idaho Power Company First RevisedOriginal Sheet No. 87-14
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

501 - 600 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.01 2016 0.86
2017 1.03 2017 0.87
2018 1.06 2018 0.89
2019 1.08 2019 0.91
2020 1.10 2020 0.93
2021 1.13 2021 0.95
2022 0.97
2023 1.00
2024 1.02
2025 1.04
2026 1.06
2027 1.09
2028 1.11
2029 1.13
2030 1.16
2031 1.19
2032 1.21
2033 1.24
2034 1.26
2035 1.29
2036 1.32
2037 1.35
2038 1.38
2039 1.41
2040 1.44
2041 1.47

Idaho Power Company First RevisedOriginal Sheet No. 87-15
Cancels
I.P.U.C. No. 2930, Tariff No. 101Original First Revised Sheet No. 87-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

601 - 700 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.12 2016 0.95
2017 1.15 2017 0.97
2018 1.17 2018 0.99
2019 1.20 2019 1.01
2020 1.22 2020 1.03
2021 1.25 2021 1.06
2022 1.08
2023 1.10
2024 1.13
2025 1.15
2026 1.18
2027 1.20
2028 1.23
2029 1.26
2030 1.29
2031 1.31
2032 1.34
2033 1.37
2034 1.40
2035 1.43
2036 1.46
2037 1.50
2038 1.53
2039 1.56
2040 1.60
2041 1.63

Idaho Power Company Original Sheet No. 87-16
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

701 - 800 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.17 2016 0.99
2017 1.20 2017 1.01
2018 1.22 2018 1.03
2019 1.25 2019 1.06
2020 1.28 2020 1.08
2021 1.30 2021 1.10
2022 1.13
2023 1.15
2024 1.18
2025 1.20
2026 1.23
2027 1.26
2028 1.28
2029 1.31
2030 1.34
2031 1.37
2032 1.40
2033 1.43
2034 1.46
2035 1.49
2036 1.53
2037 1.56
2038 1.60
2039 1.63
2040 1.67
2041 1.70

Idaho Power Company Original Sheet No. 87-17
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

801 - 900 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.16 2016 0.98
2017 1.19 2017 1.00
2018 1.21 2018 1.03
2019 1.24 2019 1.05
2020 1.27 2020 1.07
2021 1.30 2021 1.09
2022 1.12
2023 1.14
2024 1.17
2025 1.19
2026 1.22
2027 1.25
2028 1.28
2029 1.30
2030 1.33
2031 1.36
2032 1.39
2033 1.42
2034 1.45
2035 1.48
2036 1.52
2037 1.55
2038 1.59
2039 1.62
2040 1.66
2041 1.69

Idaho Power Company Original Sheet No. 87-18
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

901 - 1000 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.12 2016 0.94
2017 1.14 2017 0.96
2018 1.17 2018 0.99
2019 1.19 2019 1.01
2020 1.22 2020 1.03
2021 1.25 2021 1.05
2022 1.08
2023 1.10
2024 1.12
2025 1.15
2026 1.17
2027 1.20
2028 1.23
2029 1.25
2030 1.28
2031 1.31
2032 1.34
2033 1.37
2034 1.40
2035 1.43
2036 1.46
2037 1.49
2038 1.52
2039 1.56
2040 1.59
2041 1.63

Idaho Power Company Original Sheet No. 87-19
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1001 - 1100 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.06 2016 0.90
2017 1.08 2017 0.92
2018 1.11 2018 0.94
2019 1.13 2019 0.96
2020 1.16 2020 0.98
2021 1.18 2021 1.00
2022 1.02
2023 1.04
2024 1.07
2025 1.09
2026 1.11
2027 1.14
2028 1.16
2029 1.19
2030 1.22
2031 1.24
2032 1.27
2033 1.30
2034 1.33
2035 1.36
2036 1.39
2037 1.42
2038 1.45
2039 1.48
2040 1.51
2041 1.54

Idaho Power Company Original Sheet No. 87-20
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1101 - 1200 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.03 2016 0.87
2017 1.05 2017 0.89
2018 1.08 2018 0.91
2019 1.10 2019 0.93
2020 1.12 2020 0.95
2021 1.15 2021 0.97
2022 0.99
2023 1.01
2024 1.04
2025 1.06
2026 1.08
2027 1.11
2028 1.13
2029 1.16
2030 1.18
2031 1.21
2032 1.23
2033 1.26
2034 1.29
2035 1.32
2036 1.35
2037 1.37
2038 1.41
2039 1.44
2040 1.47
2041 1.50

Idaho Power Company Original Sheet No. 87-21
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1201 - 1300 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.07 2016 0.90
2017 1.09 2017 0.92
2018 1.12 2018 0.94
2019 1.14 2019 0.97
2020 1.17 2020 0.99
2021 1.19 2021 1.01
2022 1.03
2023 1.05
2024 1.08
2025 1.10
2026 1.12
2027 1.15
2028 1.17
2029 1.20
2030 1.23
2031 1.25
2032 1.28
2033 1.31
2034 1.34
2035 1.37
2036 1.40
2037 1.43
2038 1.46
2039 1.49
2040 1.52
2041 1.56

Idaho Power Company Original Sheet No. 87-22
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1301 - 1400 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.24 2016 1.05
2017 1.27 2017 1.07
2018 1.30 2018 1.10
2019 1.33 2019 1.12
2020 1.36 2020 1.15
2021 1.39 2021 1.17
2022 1.20
2023 1.22
2024 1.25
2025 1.28
2026 1.31
2027 1.33
2028 1.36
2029 1.39
2030 1.42
2031 1.46
2032 1.49
2033 1.52
2034 1.55
2035 1.59
2036 1.62
2037 1.66
2038 1.70
2039 1.73
2040 1.77
2041 1.81

Idaho Power Company Original Sheet No. 87-23
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 332563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1401 - 1500 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 1.61 2016 1.36
2017 1.65 2017 1.39
2018 1.69 2018 1.42
2019 1.72 2019 1.46
2020 1.76 2020 1.49
2021 1.80 2021 1.52
2022 1.55
2023 1.59
2024 1.62
2025 1.66
2026 1.70
2027 1.73
2028 1.77
2029 1.81
2030 1.85
2031 1.89
2032 1.93
2033 1.97
2034 2.02
2035 2.06
2036 2.11
2037 2.15
2038 2.20
2039 2.25
2040 2.30
2041 2.35

Idaho Power Company Original Sheet No. 87-24
Cancels
I.P.U.C. No. 2930, Tariff No. 101 Original Sheet No. 87-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33563 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 August 9, 2016 1221 West Idaho Street, Boise, Idaho

SCHEDULE 87
INTERMITTENT GENERATION INTEGRATION CHARGES
(Continued)

SOLAR INTEGRATION CHARGES (Continued)

1501 - 1600 MW Solar Capacity Penetration Level

LEVELIZED NON-LEVELIZED
ON-LINE YEAR
20 YEAR
CONTRACT
TERM
LEVELIZED
RATES
($/MWh)
CONTRACT
YEAR
NON-
LEVELIZED
RATES
($/MWh)

2016 2.26 2016 1.91
2017 2.31 2017 1.95
2018 2.36 2018 2.00
2019 2.41 2019 2.04
2020 2.47 2020 2.09
2021 2.52 2021 2.13
2022 2.18
2023 2.23
2024 2.28
2025 2.33
2026 2.38
2027 2.43
2028 2.48
2029 2.54
2030 2.59
2031 2.65
2032 2.71
2033 2.77
2034 2.83
2035 2.89
2036 2.95
2037 3.02
2038 3.09
2039 3.15
2040 3.22
2041 3.29

Idaho Power Company Third RevisedOriginal Sheet No. 89-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Second Third Revised Sheet No. 89-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33049 Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 1, 2014 1221 West Idaho Street, Boise, Idaho

SCHEDULE 89
UNIT AVOIDED ENERGY COST
FOR COGENERATION AND SMALL
POWER PRODUCTION

AVAILABILITY

Service under this schedule is available in the service territory area of Idaho Power Company in
the State of Idaho.

APPLICABILITY

Service under this schedule is applicable to any Seller who owns or operates a Qualifying Facility
supplying the Company with both Capacity and Energy under Option 3 or 4 of a Power Sales Agreement.

DEFINITIONS

Capacity means the ability of the facility to generate electric power, expressed in kW, less station
use and less step-up transformation losses to the high voltage bus at the generator site.

Cogeneration Facility means equipment used to produce electric energy and forms of useful
thermal energy (such as heat or steam), used for industrial, commercial, heating or cooling purposes,
through the sequential use of energy.

Company means the Idaho Power Company.

Qualifying Facility or Facility means a Cogeneration Facility or a Small Power Production Facility
which meets the criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title
18, of the Code of Federal Regulations.

Seller as used herein means any individual, partnership, corporation, association, governmental
agency, political subdivision, municipality or other entity that owns or operates a Qualifying Facility.

Small Power Production Facility means the equipment used to produce electric energy solely by
the use of biomass, waste, solar power, wind or any other renewable resource.

MONTHLY PAYMENTS

The Company will compensate the Seller for the energy delivered and accepted each month
under the terms of the Power Sales Agreement at the following rate:

4.133¢ per kWh for all kWh

Idaho Power Company Tenth RevisedOriginal Sheet No. 91-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Ninth Tenth Revised Sheet No. 91-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35428 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 15, 2022January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 91
ENERGY EFFICIENCY RIDER

APPLICABILITY

This schedule is applicable to all retail Customers served under the Company’s schedules and
special contracts. This Energy Efficiency Rider is designed to fund the Company’s expenditures for the
analysis and implementation of energy conservation and demand response programs.

MONTHLY CHARGE

The Monthly Charge is equal to the applicable Energy Efficiency Rider percentage times the
sum of the monthly billed charges for the base rate components.

Schedule Energy Efficiency Rider

Schedule 1 3.102.35%
Schedule 3 3.102.35%
Schedule 4 3.10%
Schedule 5 3.102.35%
Schedule 6 3.102.35%
Schedule 7 3.102.35%
Schedule 8 3.102.35%
Schedule 9 3.102.35%
Schedule 15 3.102.35%
Schedule 19 3.102.35%
Schedule 20 3.102.35%
Schedule 24 3.102.35%
Schedule 40 3.102.35%
Schedule 41 3.102.35%
Schedule 42 3.102.35%
Schedule 26 3.102.35%
Schedule 29 3.102.35%
Schedule 30 3.102.35%
Schedule 32 3.102.35%
Schedule 33 2.35%
Schedule 34 2.35%

Idaho Power Company Twelfth RevisedOriginal Sheet No. 95-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Eleventh Twelfth Revised Sheet No. 95-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. – August 18, 2023 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – September 28, 2023January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 23-

SCHEDULE 95
ADJUSTMENT FOR MUNICIPAL
FRANCHISE FEES

PURPOSE

The purpose of this schedule is to set forth the charges such as license, privilege, franchise,
business, occupation, operating, excise, sales or use of street taxes or other charges imposed on the
Company by municipal corporations and billed separately by the Company to its Customers within the
corporate limits of a municipality pursuant to Idaho Code § 50-329A.

APPLICABILITY

This schedule is applicable to all bills for Electric Service calculated under the Company’s
schedules and special Contracts in the Company’s service area within the State of Idaho as provided in
Rule C of this Tariff.

CHARGE

The rates and charges for Electric Service provided under the Company’s schedules will be
proportionately increased by the following charge within the municipality on and after the effective date
of the charge for the applicable municipal ordinance, which charge will be separately stated on the
Customer’s regular billing.

Effective Date
Municipality Ordinance No. Of Charge Charge

City of Aberdeen 303 July 31, 2015 1%
City of American Falls 659 September 28, 2023 1%
City of Bellevue 2008-06 February 28, 2008 3%
City of Blackfoot 2133 October 1, 2015 1%
City of Bliss 13-71 September 26, 2013 1%
City of Boise 6820 October 1, 2012 1.5%
City of Buhl 8351013 November 20, 1997 1%
City of Caldwell 2133 June 26, 1996 1%
City of Cambridge 7-2020 January 29, 2021 1%
City of Carey 2017-02 September 28, 2017 1%
City of Cascade 537712 November 16, 1995 1%
City of Chubbuck 498 January 21, 1999 1%
City of Council 362 September 1, 2000 1%
City of Crouch 2019-09 May 28, 2020 1%
City of Dietrich 2007-1 September 27, 2007 1%
City of Donnelly 231 August 30, 2016 1%
City of Eagle 349514 December 29, 2010 1%
City of Eden 2015-3 November 2, 2015 1%
City of Emmett 858 June 26, 1996 1%

Idaho Power CompanyTwenty-Fourth RevisedOriginal Sheet No. 95-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101 TTwenty-Third Fourth Revised Sheet No. 95-2
IDAHO Issued by IDAHO POWER COMPANY
Issued – April 23, 2021per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 27, 2021January 1, 2024 1221 West Idaho Street, Boise, Idaho
Advice No. 21-01

SCHEDULE 95
ADJUSTMENT FOR MUNICIPAL
FRANCHISE FEES
(Continued)

CHARGE (Continued)

Effective Date
Municipality Ordinance No. Of Charge Charge

City of Fairfield 253291 August 29, 2013 1%
City of Filer 574 September 30, 2009 2%
City of Fruitland 393 March 21, 2001 1%
City of Garden City 850-06 September 27, 2006 3%
City of Glenns Ferry 452 March 24, 1999 1%
City of Gooding 689 December 2, 2014 1%
City of Grand View 99-42009-1 January 21, 2000 1%
City of Greenleaf 136 October 22, 1999 1%
City of Hagerman 1090 May 27, 2021 1%
City of Hailey 10571278 August 29, 2019 3%
City of Hazelton 258-2019 April 16, 2019 1%
City of Hollister 04-03-19 June 28, 2019 1%
City of Idaho City 252363 September 25, 1996 1%
City of Inkom 96-19521-263 July 26, 1996 1%
City of Jerome 1137 April 1, 2015 1%
City of Ketchum 10921246 May 18, 2012 3%
City of Kimberly 622 May 1, 2015 1%
City of Leadore 2018-1 October 2, 2018 1%
City of McCall 862 April 29, 2009 3%
City of Melba 212 February 28, 2007 1%
City of Meridian 800 December 22, 1998 1%
City of Middleton 287 October 22, 1999 1%
City of Mountain Home 1251 October 24, 1996 1%
City of Nampa 3980 October 1, 2012 1.5%
City of New Meadows 306-06 May 30, 2007 3%
City of New Plymouth 331 January 31, 2011 1.5%
City of Notus 259 August 28, 2007 1%
City of Oakley 12-12-0102-10-22 March 30, 2012 1%
City of Payette 1476 September 29, 2020 1%
City of Pocatello 2956 November 2, 2015 1%
City of Richfield 175262 March 27, 1996 3%
City of Rockland 30 April 16, 2019 1%
City of Shoshone 514 June 27, 2008 1%
City of Star 196 August 20, 2009 1%
City of Sun Valley 519 January 26, 2018 1%
City of Twin Falls 2927 March 31, 2008 3%
City of Wendell 529-2016 September 29, 2016 1%
City of Wilder 486 May 27, 2004 1%

Idaho Power Company Original Sheet No. 96-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101_ Original Sheet No. 96-1

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35452 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 28, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 96
BLAINE COUNTY SURCHARGE
TO FUND THE UNDERGROUNDING
OF CERTAIN FACILITIES

PURPOSE

The purpose of this schedule is to set forth the monthly surcharge to fund the incremental cost of
undergrounding certain transmission and distribution facilities at the request of Blaine County. The
monthly surcharge will be billed separately by the Company to its Customers within the corporate limits
of Blaine County.

APPLICABILITY

This schedule is applicable to all Customers served under the Company’s schedules listed below
within the corporate limits of Blaine County.

CHARGE

The applicable monthly surcharge will be applied to Customers’ bills starting on the first bill date
of the month following energization of the facilities and will remain in effect throughout the payback period.
The payback period is assumed to be twenty (20) years. Any over- or under-collection relative to actual
incremental project costs may be addressed through surcharge modification and/or increases or
decreases to the payback period.

Schedule Description Monthly Surcharge
1 Residential Service $3.42
3 Master Metered Mobile Home Park $3.42
5 Residential – Time-of-Day Pilot Plan $3.42
6 Residential Service On-Site Generation $3.42
7 Small General Service $3.42
8 Small General Service On-Site Generation $3.42 
9S Large General Service – Secondary $14.36
9P Large General Service – Primary $14.36
9T Large General Service – Transmission $14.36
19S Large Power Service – Secondary $14.36
19P Large Power Service – Primary $14.36
19T Large Power Service – Transmission $14.36
24 Agricultural Irrigation Service $14.36

Idaho Power Company Fifth RevisedOriginal Sheet No. 98-1
Cancels
I.P.U.C. No. 2930, Tariff No. 101Fourth Fifth Revised Sheet No. 98-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.– May 14, 2019 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 June 14, 2019 1221 West Idaho Street, Boise, Idaho
Advice No. 19-06

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT

APPLICABILITY

This schedule is applicable to the Qualifying Electric Energy, as defined below, delivered to
Customers taking service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 15, or 24.

The Residential and Small Farm Energy Credit (“Credit”) is the result of the Settlement Agreement
between the Company and the Bonneville Power Administration (“BPA”) Contract No. 11PB-12322. The
Settlement Agreement provides for the determination of benefits during the period October 1, 2011,
through September 30, 2028. This schedule shall expire when the benefits derived from the Settlement
Agreement have been credited to Customers as provided for under this schedule.

QUALIFYING ELECTRIC ENERGY

RESIDENTIAL

All kilowatt-hours (kWh) of metered energy, delivered during the Billing Period, to
residential Customers taking service under Schedules 1, 3, 4, 5, or 6 and all kWh of metered
residential electric use delivered to Customers taking service under Schedules 7, 8, 9, or 15, as
defined in the BPA Customer Load Eligibility Guidelines for the Residential Exchange Program
Residential Purchase and Sale Agreements, will be considered Residential Qualifying Electric
Energy under this schedule.

SMALL FARM

All kWh of metered energy, delivered during the Billing Period, to eligible small farm
Customers taking service under Schedule 7, 8, or 9, as defined in the BPA Customer Load
Eligibility Guidelines for the Residential Exchange Program Residential Purchase and Sale
Agreements will be considered Small Farm Qualifying Electric Energy under this schedule.

IRRIGATION

All kWh of metered energy, delivered during the Billing Period, to eligible irrigation
Customers taking service under Schedule 24, as defined in the BPA Customer Load Eligibility
Guidelines for the Residential Exchange Program Residential Purchase and Sale Agreements,
limited to either the irrigation Customer’s actual metered energy or 222,000 kWh, whichever is
less, will be considered Irrigation Qualifying Electric Energy under this schedule. Determination
of Irrigation Qualifying Electric Energy under this schedule will be identified at the Customer level.

Idaho Power Company Fourth RevisedOriginal Sheet No. 98-2
Cancels
I.P.U.C. No. 2930, Tariff No. 101Third Fourth Revised Sheet No. 98-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35269 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 January 1, 2022 1221 West Idaho Street, Boise, Idaho

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT
(Continued)

CREDIT ADJUSTMENT

An energy credit rate will be determined on an annual basis by dividing the sum of the total fiscal
year Credit, derived from the Settlement Agreement, plus a true up from the prior year Credit, if
applicable, by the sum of the calendar year projected Qualifying Electric Energy as described above.
The current energy credit rate is 0.2534 cents per kWh.

For residential and small farm Customers, the adjustment credit will be reflected on Customers’
monthly bills.

For irrigation Customers, the adjustment credit will be issued in December of each year.