20251024Motion for Approval of Stipulation and Settlement.pdf

a DAHO R®
DONOVAN E. WALKER
Lead Counsel RECEIVED
dwalker(aDidahopower.com OCTOBER 24, 2025
IDAHO PUBLIC
UTILITIES COMMISSION
October 24, 2025
VIA ELECTRONIC FILING
Commission 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-25-16
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 Authority to Implement Certain Measures to Mitigate the Impact of
Regulatory Lag
Dear Commission Secretary:
Attached for electronic filing is the Motion for Approval of Stipulation and
Settlement and Request for Accounting Order and the Direct Testimony of Timothy E.
Tatum in Support of Settlement Stipulation in the above-referenced matter.
If you have any questions, please do not hesitate to contact me.
Very truly yours,
'6.� 'G')&g
Donovan E. Walker
DEW:cd
Attachments
1221 W. Idaho St(83702)
P.O.Box 70
Boise, ID 83707

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]
dwalkerCcDidahopower.com
mgoicoecheaallenCa�_idahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-25-16
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC ) MOTION FOR APPROVAL OF
SERVICE IN THE STATE OF IDAHO ) STIPULATION AND SETTLEMENT
AND AUTHORITY TO IMPLEMENT ) AND REQUEST FOR ACCOUNTING
CERTAIN MEASURES TO MITIGATE ) ORDER
THE IMPACT OF REGULATORY LAG. )
COMES NOW, Idaho Power Company ("Idaho Power" or"Company"), and hereby
moves the Commission pursuant to Commission Rules of Procedure' 56 and 274, 275,
and 276 for an Order accepting the Stipulation and Settlement ("Stipulation") entered into
by and among Idaho Power, the Staff of the Idaho Public Utilities Commission ("Staff"),
and the following intervenors in this docket: City of Boise, Clean Energy Opportunities for
Idaho ("CEO"), Federal Executive Agencies ("FEA"), Idaho Irrigation Pumpers
Association, Inc. ("IIPA"), Industrial Customers of Idaho Power ("ICIP"), Kroger Co.
("Kroger"), Micron Technology, Inc. ("Micron"), and NW Energy Coalition ("NWEC")
' Hereinafter cited as RP or"Procedural Rule".
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 1

(collectively referred to as the "Stipulating Parties"). Additionally, in order to facilitate
implementation of one of the terms of the Stipulation related to adjustments to plant in
service as described in Section II, below, the Company respectfully requests Commission
authorization to retain in Construction Work in Progress ("CWIP") the costs associated
with the distribution undergrounding portion of the Wood River Valley ("WRV") project
until such time that the entire project is completed and placed into service.
This Motion is based on the Direct Testimony of Timothy E. Tatum in Support of
Settlement Stipulation filed contemporaneously herewith; the signed Stipulation and
accompanying Exhibit Nos. 1 through 5 memorializing the Stipulating Parties' agreement
included as Attachment No. 1; the revised tariff sheets provided in Attachment No. 2; and
the following:
I. STIPULATION AND SETTLEMENT
1. On May 30, 2025, Idaho Power filed an Application with the Commission
requesting an increase in annual Idaho jurisdictional revenue of $199.1 million, which if
approved would have resulted in an overall increase to adjusted base revenue of 13.09
percent. Idaho Power proposed spreading the rate increase to varying degrees among
all customer classes and special contract customers. On June 13, 2025, the Commission
issued Order No. 36638, which, in pertinent part, designated the proceeding as a general
rate case pursuant to Procedural Rule 124 and suspended the effective date of the
proposed rates for a period of thirty (30) days plus five (5) months from July 1, 2025, to
effectuate review of the Company's request in accordance with Idaho Code § 61-622(4)
and Procedural Rule 123.03.
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 2

2. Petitions to intervene in this proceeding were filed by the City of Boise,
CEO, FEA, IIPA, IdaHydro, ICIP, Kroger, Micron, NWEC, and John Gannon, Deborah
Fease, Amy Lorrance, and Randy Morris ("Gannon, et al., pro se"). These entities are
collectively referred to as the "Parties." By various orders, the Commission granted these
interventions. IPUC Order Nos. 36557, 36635, 36665, 36666, 36685, 36690, and 36691 .
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 also agreed to engage in settlement discussions in accordance with Procedural
Rule 272 with a view toward resolving the issues in this case, and Commission Staff
provided notice of settlement negotiations to all parties of record on September 2, 2025.
All Parties were given an opportunity, whether in person or virtually, to participate in or be
apprised of the course of settlement negotiations, which were held on September 9,
September 29, and October 6, 2025.
4. Based on the settlement discussions, the following Parties whose
signatures appear on the Stipulation have agreed to resolve and settle all the issues in
the case: Idaho Power, Staff, City of Boise, CEO, FEA, IIPA, ICIP, Kroger, Micron, and
NWEC. Gannon, et al., pro se and IdaHydro did not join in the Stipulation; the former has
indicated it will not object to the settlement while the latter has not indicated a position.
5. If the Stipulation is approved, the Company's overall Idaho jurisdictional
retail revenue will increase by approximately $110 million, or 7.48 percent.
6. For settlement purposes and subject to Commission approval, the
Stipulating Parties agree that the revenue requirement increase contemplated by the
Stipulation should be recovered by implementing tariffs in conformance with those in
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 3

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.
7. The Stipulating 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.
8. A technical hearing is scheduled to take place in Boise starting on
December 2 and continuing as needed through December 5, 2025. 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 page 17 of the Stipulation, all the Stipulating
Parties agree that the Stipulation is in the public interest and represents a fair, just, and
reasonable compromise of the issues in this proceeding.
II. ACCOUNTING ORDER AND TREATMENT
9. As set forth in Section A(2)(b) and paragraph 16 of the Stipulation, the
Stipulating Parties have agreed that the costs associated with the distribution
undergrounding portion of the WRV project should be removed from the revenue
requirement in this case and retained in CWIP until the entire project (both distribution
and transmission) is completed and placed in service. To implement the Stipulating
Parties' agreement in this regard, the Company respectfully requests that the
Commission issue an accounting order authorizing this treatment, which is consistent with
the accounting order granted by the Commission in Order No. 36687 authorizing the delay
in placing the incremental distribution costs attributable to Blaine County — recorded in
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER-4

CWIP — into service until the transmission line is complete and operational, allowing for
a single surcharge for the incremental WRV project costs attributable to Blaine County.
III. REQUEST FOR RELIEF
NOW, THEREFORE, Idaho Power respectfully requests that the Commission
issue a final order:
1. Granting this Motion and accepting the Stipulation and Settlement agreed
to by the Stipulating Parties and provided as Attachment No. 1 hereto, in its entirety
without material change or condition;
2. Authorizing the Company to implement revised tariff schedules designed to
recover $110 million in additional annual revenue from its Idaho jurisdiction consistent
with the terms of the Stipulation, provided as Attachment No. 2 hereto, effective
January 1, 2026; and
3. Authorizing Idaho Power to retain costs associated with the distribution
undergrounding portion of the WRV project in CWIP until the entire project (distribution
and transmission) is completed and placed in service.
Respectfully submitted this 24th day of October 2025.
'Z.�.� '5;Z
�J -
DONOVAN E. WALKER
Attorney for Idaho Power Company
�-/O I W�uq I
MEGAN GOICOECHEA ALLEN
Attorney for Idaho Power Company
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 5

CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 24t" day of October 2025, 1 served a true and
correct copy of the Motion for Approval of Stipulation and Settlement and Request for
Accounting Order upon the following named parties by the method indicated below, and
addressed to the following:
Commission Staff Hand Delivered
Erika Melanson U.S. Mail
Deputy Attorney General Overnight Mail
Idaho Public Utilities Commission FTP Site
11331 W. Chinden Blvd., Bldg No. 8 X Email
Suite 201-A (83714) erika.malanson(apuc.idaho.gov
PO Box 83720
Boise, ID 83720-0074
Idaho Irrigation Pumpers Association, Hand Delivered
Inc. U.S. Mail
Eric L. Olsen Overnight Mail
Echo Hawk & Olsen, PLLC FTP Site
505 Pershing Ave., Ste. 100 X Email
P.O. Box 6119 elo echohawk.com
Pocatello, Idaho 83205
Lance Kaufman, Ph.D. Hand Delivered
2623 NW Bluebell Place U.S. Mail
Corvallis, OR 97330 Overnight Mail
FTP Site
X Email
lance aegisinsight.com
Clean Energy Opportunities for Idaho Hand Delivered
Kelsey Jae U.S. Mail
Law for Conscious Leadership Overnight Mail
920 N. Clover Dr. FTP Site
Boise, ID 83703 X Email
Kelsey(o)_kelseylae.com
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 6

Courtney White Hand Delivered
Mike Heckler U.S. Mail
3778 Plantation River Drive, Suite 102 Overnight Mail
Boise, Idaho 83703 FTP Site
X Email
Courtney(cD_cleanenergyopportunities.com
mike _cleanenergyopportunites.com
City of Boise City Hand Delivered
Ed Jewell U.S. Mail
Deputy City Attorney Overnight Mail
Boise City Attorney's Office FTP Site
150 N. Capital Blvd., X Email
P.O. Box 500 ediewell _cityofboise.org
Boise, Idaho 83701 BoiseCityAttorneyCa�.cityofboise.org
Katie O'Neil Hand Delivered
Energy Program Manager U.S. Mail
Boise City Dept. of Public Works Overnight Mail
150 N. Capitol Blvd. FTP Site
P.O. Box 500 X Email
Boise, Idaho 83701-0500 koneilCcDcityofboise.org
Federal Executive Agencies Hand Delivered
Emily W. Medlyn U.S. Mail
Jelani A. Freeman Overnight Mail
U.S. Department of Energy FTP Site
1000 Independence Ave., S.W. X Email
Washington, D.C. 20585 emily.medlyn(a)_hg.doe.gov
Jelani.freemen(b,hg.doe.gov
Dwight Etheridge Hand Delivered
Exeter Associates, Inc. U.S. Mail
10480 Little Patuxent Parkway, Suite 300 Overnight Mail
Columbia, MD 21044 FTP Site
X Email detheridge(�bexeterassociates.com
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 7

IdaHydro Hand Delivered
C. Tom Arkoosh U.S. Mail
Nicholas J. Erekson Overnight Mail
Arkoosh Law Offices FTP Site
913 W. River Street, Suite 450 X Email
P.O. Box 2900 tom.arkoosh(oarkoosh.com
Boise, ID 83701 nick.erekson(Darkoosh.com
Erin.cecil(a)_arkoosh.com
The Kroger Co. Hand Delivered
Kurt J. Boehm U.S. Mail
Jody Kyler Cohn Overnight Mail
Boehm, Kurtz & Lowry FTP Site
425 Walnut Street, Suite 2400 X Email
Cincinnati, OH 45202 kboehm bkllawfirm.com
jkylercohn _bkllawfirm.com
Micron Technology, Inc. Hand Delivered
Austin Rueschhoff U.S. Mail
Thorvald A. Nelson Overnight Mail
Kristine A.K. Roach FTP Site
Holland & Hart, LLP X Email
555 17th Street, Suite 3200 darueschhoff(o)_hol land hart.corn
Denver, CO 80202 tnelson _hol land ha rt.corn
awjensen _hollandhart.com
karoach hollandhart.com
aclee hollandhart.com
tlfriel hollandhart.com
Industrial Customers of Idaho Power Hand Delivered
Peter Richardson U.S. Mail
Richardson Adams, PLLC Overnight Mail
515 N. 27th Street FTP Site
Boise, Idaho 83702 X Email
peter _richardsonadams.com
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 8

Northwest Energy Coalition Hand Delivered
Benjamin J. Otto U.S. Mail
Lauren McCloy Overnight Mail
Derek Goldman FTP Site
Northwest Energy Coalition X Email
1407 W. Cottonwood Court ben(o)-nwenergy.org
Boise, Idaho 83702 lauren _nwenergy.org
derek(c)-nwenergy.org
John Gannon Hand Delivered
1104 Johnson Street U.S. Mail
Boise, Idaho 83705 Overnight Mail
FTP Site
X Email
Johngannon200(a-),gmail.com
Occidentalpacific(a-),hotmail.com
Feased854(o)_gmail.com
(I
Christy Davenport
Legal Administrative Assistant
MOTION FOR APPROVAL OF STIPULATION AND SETTLEMENT AND REQUEST FOR ACCOUNTING
ORDER- 9

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
ATTACHMENT NO. 1

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
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]
dwalker(a�idahopower.com
mgoicoecheaallenCo)_idahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-25-16
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC ) STIPULATION AND SETTLEMENT
SERVICE IN THE STATE OF IDAHO )
AND AUTHORITY TO IMPLEMENT )
CERTAIN MEASURES TO MITIGATE )
THE IMPACT OF REGULATORY LAG. )
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 the following intervenors in this docket: City of Boise, Clean
Energy Opportunities for Idaho ("CEO"), Federal Executive Agencies ("FEA"), Idaho
Irrigation Pumpers Association, Inc. ("IIPA"), Industrial Customers of Idaho Power
("ICIP"), Kroger Co. ("Kroger"), Micron Technology, Inc. ("Micron"), and NW Energy
Coalition ("NWEC"). These entities are referred to individually as a "Stipulating Party" or
collectively referred to as the "Stipulating Parties."
STIPULATION AND SETTLEMENT- 1

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
I. INTRODUCTION
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 approximately$110 million,
or 7.48 percent. The Stipulating 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 Stipulating 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 Stipulating Parties recommend
that the Commission, in accordance with Commission Rule of Procedure' 274, approve the
Stipulation and all of its terms and conditions without material change or condition.
II. BACKGROUND
On May 30, 2025, Idaho Power filed an Application with the Commission
requesting an increase in annual Idaho jurisdictional revenue of $199.1 million, which if
approved would have resulted in an overall increase to adjusted base revenue of 13.09
percent. Idaho Power proposed spreading the rate increase to varying degrees among
all customer classes and special contract customers. Anticipating suspension of the
proposed tariff pursuant to Idaho Code § 61-622(4) and Procedural Rule 123.03, the
Company requested that new rates become effective on January 1, 2026. Idaho Power
notified customers of the requested rate increase via press release and customer notices
mailed to individual customers in accordance with the requirements of Procedural Rule
125.
Hereinafter cited as"Procedural Rule".
STIPULATION AND SETTLEMENT-2

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
To facilitate review of the Company's request, on June 13, 2025, the Commission
designated the proceeding as a general rate case pursuant to Procedural Rule 124 and
notified the public in Order No. 36638 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 or until the Commission enters an order accepting,
rejecting, or modifying the proposed rate increases.
Petitions to intervene in this proceeding were filed by the City of Boise, CEO, FEA,
IIPA, IdaHydro, ICIP, Kroger, Micron, NWEC, and John Gannon, Deborah Fease, Amy
Lorrance, and Randy Morris ("Gannon, et al., pro se). These entities are collectively
referred to as the "Parties." By various orders, the Commission granted these
interventions. IPUC Order Nos. 36557, 36635, 36665, 36666, 36685, 36690, and 36691.
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 Procedural
Rule 272 with a view toward resolving the issues in this case. All Parties attended,
whether in person or virtually, settlement discussions held on September 9, September
29, and October 6, 2025.
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 Stipulating
Parties agree to the following terms:
STIPULATION AND SETTLEMENT- 3

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
III. TERMS OF THE STIPULATION AND SETTLEMENT
A. Revenue Requirement
The Stipulating Parties agree that Idaho Power shall be allowed to increase annual
Idaho jurisdictional retail revenues by approximately $110 million, or 7.48 percent,
effective January 1, 2026. The Stipulating Parties further agree that the $110 million
increase represents a compromise of the revenue requirement positions in 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 approximately
$110 million additional revenue requirement, the Stipulating 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 will not be construed as precedent in any subsequent
proceeding before the Commission.
STIPULATION AND SETTLEMENT-4

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Summary of Stipulated Revenue Requirement Adjustments
(Figures reflect Idaho Jurisdictional Amounts
Filed Net Revenue Increase: $199,122,685
Stipulated Adjustments Adjustment Net Rate Change
Impact
1. Cost of Capital
a. Return on Equity $27,687,577 $171,435,108
2. Rate Base
b. Adjustments to Plant in Service $21,605,673 $149,829,436
c. Customer Advances — Update to Actuals $1,411,447 $148,417,989
d. Customer Advances — BPA $986,816 $147,431,173
3. Revenue
e. Revenue Forecast— Update to Actuals $9,054,540 $138,376,633
4. Ex enses
f. Executive Comp, Training, and Travel $3,919,804 $134,456,829
g. Board of Directors Comp and Expenses $1,313,083 $133,143,746
h. Miscellaneous Adjustments $1,223,909 $131,919,837
5. Deferrals and Mechanisms
i. Wildfire O&M Base Update $10,722,564 $121,197,273
j. Insurance Base $5,328,358 $115,868,915
k. Wildfire Deferral Amortization $2,646,864 $113,222,051
I. Net Power Cost Update — Gas Prices $2,186,414 $111,035,637
m. Net Power Cost Update — EIM Benefits $995,491 $110,040,145
1. Cost of Capital
(a) Cost of Capital. The Stipulating Parties agree to a 9.6 percent return
on equity ("ROE") and a 7.410 percent overall rate of return ("ROR") based on the filed
cost of debt and capital structure, applied to an authorized Idaho jurisdictional rate base
of$4,881,563,721.
2. Rate Base
(b) Adjustments to Plant in Service. The Stipulating Parties agree to
reduce the test year revenue requirement by $21,605,673 to account for the following: (1)
modification to the plant forecast from a 13-month average to a December 2025 average of
monthly averages ("AMA") utilizing actual plant additions for January through July 2025, (2)
removal of the annualizing adjustments associated with projects over$2 million, (3) updating
STIPULATION AND SETTLEMENT- 5

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
the forecast for projects under$2 million based on actual plant additions for January through
July 2025, (4) removal of the C.J. Strike Boat Barrier project, which is not expected to close
to plant in 2025, and (5) removal of the Wood River Valley ("WRV") distribution line.
(c) Customer Advances — Update to Actuals. The Stipulating Parties
agree to reduce the filed request by $1,411,447 to reflect higher actual customer advance
balances as of July 2025 compared to the forecasted balances included in the original filing.
(d) Customer Advances — BPA. The Stipulating Parties agree to reduce
the filed request by $986,816 to include the Boardman to Hemingway seller's security
deposit received from the Bonneville Power Administration ("BPA").
3. Revenues
(e) Revenue Forecast. The Stipulating Parties agree to reduce the filed
request by $9,054,540 to reflect an update to the revenue forecast based on actual
revenue through July 2025.
4. Expenses
(f) Executive Compensation, Training, and Travel. The Stipulating Parties
agree to reduce revenue requirement by $3,919,804 to reflect the removal of certain
executive compensation, training, and travel expenses.
(g) Board of Directors Comp and Expenses. The Stipulating Parties
agree to reduce revenue requirement by$1,313,083 to reflect the removal of one-half of the
Board of Director's compensation and certain Board of Director's expenses.
(h) Miscellaneous Administrative and General Expense Adjustments. The
Stipulating Parties agree to adjust a portion of the test year operating expenses related to
the following cost categories: (1) company airplane flights & maintenance ($355,195), (2)
STIPULATION AND SETTLEMENT-6

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
advertising ($297,372), (3) legal fees ($321,813), (4) credit card expenses ($100,000), and
(5) injuries and damages ($149,528). The net effect of these adjustments decreases the
overall revenue requirement by $1,223,909. 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.
5. Deferrals / Mechanism-Related Adjustments
(i) Wildfire Operations & Maintenance (O&M)Adiustment. The Stipulating
Parties agree 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 $211,884. The Stipulating Parties also agree to remove the
revenue requirement of $736,780 associated with the Standby Helicopter Service and the
Aerial Drone Inspection Pilot. The Stipulating Parties agree to reduce revenue requirement
by $9,773,901 to reduce Transition to/Maintain 3-year Vegetation Management Cycle to
actuals for 2024. The net effect of these adjustments decreases the overall revenue
requirement by $10,722,564.
Wildfire O&M Base Update. The following activities are eligible for deferral
through the earlier of Idaho Power's next general rate case ("GRC") or 2027: (1) incremental
vegetation management, including Transition to/Maintain 3-year Cycle, above 2024 levels
of$31,932,421, (2) incremental Enhanced Practices for Red and Yellow Risk Zones above
2025 Test Year amount of $1,486,000, (3) incremental internal Vegetation Management
Crew Pilot, and (4) the Standby Helicopter Service and the Aerial Drone Inspection Pilot.
STIPULATION AND SETTLEMENT- 7

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
The costs associated with these activities above the base amount of $33,418,4212 are
eligible for deferral. The Stipulating Parties agree that Wildfire O&M and Insurance deferred
amounts will be recorded in separate regulatory asset accounts.
(j) Insurance Base. The Stipulating Parties agree to reduce the revenue
requirement by $5,328,358 to reflect insurance actuals for 2024 compared to the test year
balance included in the original filing. Incremental insurance above the 2024 actual amount
of$20,164,4723 will continue to be deferred through the earlier of the Company's next GRC
or 2027. The Stipulating Parties agree that Wildfire O&M and Insurance deferred amounts
will be recorded in separate regulatory asset accounts.
(k) Wildfire Deferral Amortization. The Stipulating Parties agree to
reduce revenue requirement by $2,646,864 to reflect the updated amortization of the actual
wildfire deferral balance of $54,819,901 as of June 30, 2025, over a 7-year period. The
wildfire deferral balance of$54,819,901 consists of incremental wildfire O&M and insurance
expenses deferred for 2023, 2024, and year-to-date June 2025.
(1) Net Power Cost Update — Gas Prices. An adjustment was made to
update the modeling assumption related to natural gas prices that reduces filed system
Net Power Supply Expense ("NPSE") by $45.2 million. Net of the Power Cost Adjustment
("PCK) transfer adjustment, this results in a net reduction to the Company's revenue
requirement of $2,186,414.
(m) Net Power Cost Update — Energy Imbalance Market ("EIM"). An
adjustment was made to update base NPSE to incorporate an estimate of EIM benefits
2 Total system.
3 Id.
STIPULATION AND SETTLEMENT- 8

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
which reduces filed system NPSE by $20.6 million. Net of the PCA transfer adjustment,
this results in a net reduction to the Company's revenue requirement of $995,491.
B. Cost-of-Service, Revenue Allocation, and Rate Design
6. Cost-of-Service. The Stipulating Parties do not agree on any particular
class cost-of-service ("CCOS") methodology and this Stipulation does not request that
the Commission approve a particular CCOS methodology. The Company's filed CCOS
methodology, updated to reflect customer, energy, and demand allocators based on
January through July normalized actuals (consistent with the "Revenue Forecast —
Update to Actuals" adjustment described in Section A(3)(e)) and the settled revenue
requirement ("Settlement CCOS Study"), has been utilized on a limited basis to inform a
starting point for revenue allocation, Schedule 9, Schedule 19, and Schedule 30 rate
design (as further explained below), Fixed Cost Adjustment ("FCA") rates, the Sales
Based Adjustment Rate ("SBAR") used in the PCA, special contract pricing, and optional
service offerings including Schedules 31, 45, 46, and 62.
7. Revenue Allocation. The Stipulating Parties agree that the above-
described $110 million net revenue increase should be recovered by implementing tariffs
in conformance with the attached Exhibit No. 1. The revenue allocation was generally
developed using a method to increase the prices for each customer class ranging
between approximately 0.3 times (2.38 percent) to 1.3 times (9.89 percent) of the overall
7.48 percent increase.
8. Rate Design. For settlement purposes, the Stipulating Parties agree to the
rate design and related tariff provisions proposed by the Company in Mr. Grant
STIPULATION AND SETTLEMENT- 9

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Anderson's direct testimony, updated to reflect the Settlement CCOS Study, with the
following exceptions:
a. Service Charges: The existing $15 Service Charge will be retained for
Schedule 1 (Residential Service Standard Plan), Schedule 3 (Master-
Metered Mobile Home Park Residential Service), Schedule 5 (Residential
Service — Time-of-Use Plan), and Schedule 6 (Residential Service On-Site
Generation). The existing $25 Service Charge will be retained for Schedule
7 (Small General Service), Schedule 8 (Small General Service On-Site
Generation), and Schedule 9 (Large General Service - Secondary). For
Schedule 9 (Large General Service - Primary and Transmission), a Service
Charge of $345 will be implemented, for Schedule 19 (Large Power
Secondary Service), a Service Charge of$110 will be implemented, and for
Schedule 19 (Large Power— Primary and Transmission Service), a Service
Charge of$450 will be implemented.
b. Demand-Related Charges: For Schedule 9 (Large General Service —
Primary and Transmission), Schedule 19 (Large Power Service), and
Schedule 30 (Electric Service Rate for United States Department of Energy
Idaho Operations Office), the collection of demand-classified costs through
the Demand and/or Basic Load Capacity charges will reflect an approximate
40 percent movement toward cost of service for that pricing component, as
informed by the Settlement CCOS Study.
c. Non-Residential Time-of-Use ("TOU"): For Schedule 9 (Large General
Service) and 19 (Large Power Service), the TOU periods will be adjusted
STIPULATION AND SETTLEMENT- 10

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
as follows: On-Peak hours will remain consistent with the Company's filed
position, Off-Peak hours will be defined as 10 a.m. to 2 p.m., Monday
through Saturday and all hours on Sundays and Holidays; and Mid-Peak
hours will include all hours not designated as On-Peak or Off-Peak. The
method for establishing the differentials between On-Peak, Mid-Peak, and
Off-Peak will remain consistent with the Company's filed position.
The attached Exhibit No. 2 details the specific pricing for each schedule.
9. Rate Effective Date. The Stipulating Parties request that the Commission
issue an Order approving the agreed-upon rates contained in this Stipulation to become
effective on January 1, 2026.
C. Non-Revenue Stipulated Agreements
10. Single Issue CCOS Case. The Stipulating Parties agree that it would be
appropriate for the Commission to address the CCOS methodology and associated policy
issues in a separate proceeding in which alternatives to the Company's filed CCOS
methodology in this case, including a CCOS study with an hourly-informed class
allocation of Production and Transmission revenue requirement, will be presented for the
Commission's consideration. To this end, Idaho Power agrees to initiate a single-issue
case related to CCOS methodology for the Commission's consideration ("Single Issue
CCOS Case") in advance of filing a Notice of Intent for its next GRC but in no event later
than the end of the first quarter of 2026. Prior to filing that case, Idaho Power will meet
with Staff and other interested Parties to identify alternative CCOS studies that will be
presented by the Company for Commission consideration. Should Idaho Power file a
GRC prior to the issuance of a final order in the Single Issue CCOS Case, Idaho Power
STIPULATION AND SETTLEMENT- 11

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
will include a CCOS study with an hourly-informed class allocation of Production and
Transmission revenue requirement in addition to its proposed CCOS study as part of its
GRC filing. After receipt of the final order in the Single Issue CCOS Case, Idaho Power
will supplement its GRC filing to incorporate any directives stemming from the final
Commission decision. However, the results of the Single Issue CCOS Case do not
prevent any Party from proposing any alternative CCOS methodology in a GRC.
11. Test Year Methodology Workshop. In advance of the Company's next
GRC, Staff will initiate a workshop with Idaho Power and interested parties to discuss
test-year methodologies.
12. Irrigation TOU. Idaho Power commits to immediately initiate collaborative
discussions with the Idaho Irrigation Pumpers Association ("IIPA"), and other interested
parties, with the intent of developing an optional Agricultural Irrigation Service (Schedule
24) TOU offering that could be filed for IPUC approval as early as January 1, 2026, with
the newly established rate structure becoming effective on or after June 1, 2026. Issues
within scope for this collaborative effort include, but are not limited to, (1) appropriate TOU
rate periods, (2) the extent to which generation and transmission costs are to be collected
through on-peak energy charges, (3) interplay between the potential TOU offering and
the Irrigation Peak Rewards demand response program and (4) mitigation of fixed cost
revenue erosion.
13. Capital Investments. At the time of this Stipulation, Staff had completed its
prudence review of capital projects included in the test year rate base through July 2025.
Except as otherwise noted in this Stipulation, all capital projects included in the
Company's test year are presumed to be prudently incurred. To the extent Staff identifies
STIPULATION AND SETTLEMENT- 12

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
potential prudence concerns with capital investments after July 2025, it will address those
in the Company's next GRC.
14. Revenue Sharing/Accumulated Deferred Investment Tax Credit
("ADITC") Mechanism Background. 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, Order No. 34071 in Case No. GNR-
U-18-01, and Order No. 36042 in Case No. IPC-E-23-11, 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 9.12 percent. The
mechanism also provides for the potential sharing between Idaho Power and Idaho
customers of Idaho jurisdictional earnings in excess of a 9.6 percent Idaho ROE. Under
the current mechanism, the ADITC and sharing thresholds are to be reset at a GRC 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 ROE falls below 95 percent of
the authorized ROE.
15. Revenue Sharing / ADITC Mechanism Modifications. Under this
Stipulation, the ADITC Revenue Sharing Mechanism is modified to include an additional
amount of ADITC equal to the total of existing ADITC not currently eligible for accelerated
amortization under the mechanism and all available investment tax credits generated
through the end of calendar-year 2028. Further, the Stipulating Parties agree that the
maximum allowed annual accelerated amortization of ADITC will be $55 million for
calendar year 2026 and thereafter. Effective January 1, 2026, revenue sharing between
STIPULATION AND SETTLEMENT- 13

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power and Idaho customers of Idaho-jurisdictional earnings will occur if earnings
are in excess of a 9.6 percent Idaho ROE and all revenue sharing will continue to be
implemented through the PCA. The new minimum-specified Idaho ROE is set at 95
percent of the stipulated 9.6 percent, or 9.12 percent.
16. WRV Distribution Line. Pursuant to Section A(2)(b), the Stipulating Parties
agree to remove the costs associated with the distribution undergrounding portion of the
WRV project from the revenue requirement. In consideration of this removal, the
Stipulating Parties agree that the Company shall retain the distribution undergrounding
portion of the WRV project in Construction Work in Progress ("CWIP") until the entire
project (distribution and transmission) is completed and placed in service.
17. NPSE Base and PCA. For purposes of calculating the PCA, the new
system-level base NPSE is $468,840,624. The decrease to base NPSE from current
levels results in the transfer of $13.1 million from base rates to the PCA. Exhibit No. 3
attached hereto details the individual PCA component amounts by Federal Energy
Regulatory Commission account that have been agreed upon by the Stipulating Parties.
Schedule 55, Power Cost Adjustment, will be modified effective January 1, 2026, to reflect
this transfer of NPSE recovery.
18. Fixed Cost Adjustment ("FCA"). In determining the fixed cost per
customer ("FCC") and fixed costs per energy ("FCE") to be tracked through the
Company's FCA, the Stipulating Parties agree to use the Settlement CCOS Study. The
FCC and fixed costs per energy FCE effective January 1, 2026, are included in Exhibit
No. 4 for the respective FCA-applicable customer classes.
STIPULATION AND SETTLEMENT- 14

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
19. Sales Based Adjustment Rate ("SBAR"). In determining the agreed-upon
SBAR to be applied in the Company's PCA, the Stipulating Parties agree to use the
Settlement CCOS Study to determine the generation-related Idaho jurisdictional revenue
requirement that has been classified as energy-related. The resulting SBAR of $27.82
per megawatt-hour ("MWh") was developed using 2025 normalized Idaho test year retail
sales in the amount of 15,497,724 MWh as proposed by the Company in this case. Exhibit
No. 5 to the Stipulation details the derivation of the agreed upon SBAR that is to become
effective on January 1, 2026.
20. Wheeling Revenue. The Stipulating Parties agree to a baseline wheeling
tracker level of collection of $3.38 per MWh. This reflects Idaho jurisdictional point-to-
point wheeling revenues of $52,329,358 divided by Idaho jurisdictional retail sales of
15,497,724 MWh.
21. Valmy and Bridger. The Stipulating Parties agree that the stipulated
revenue requirement includes updated recovery associated with both the Valmy and
Bridger mechanisms and reflects updated capital and O&M forecasted spend, as well as
the true-up of variances between prior forecasts and actual costs through 2024. Also, the
Stipulating Parties acknowledge that in addition to the rate recovery update, the
discussion related to the Valmy coal-related investments provided in Mr. Ryan Adelman's
direct filed testimony satisfies the 2024 annual reporting required by Order No. 34349.
22. Rule H Three Phase Base Charge. The Stipulating Parties agree to
implement the following three phase base charges: $80 (underground), $1,072 (overhead
including 2" riser), and $1,352 (overhead including 3" riser), effective January 1, 2026.
STIPULATION AND SETTLEMENT- 15

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power will update charges annually when it submits its annual Rule H compliance
filing on or before December 31 of each year.
D. Other General Provisions
The Stipulating Parties agree that this Stipulation represents a compromise of the
positions of the Stipulating Parties in this case. As provided in Procedural Rule 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.
The Stipulating Parties submit this Stipulation to the Commission and recommend
approval in its entirety pursuant to Procedural Rule 274. The Stipulating Parties shall
support this Stipulation before the Commission, and no Stipulating Party shall appeal a
Commission Order approving the Stipulation or an issue resolved by the Stipulation. If
this Stipulation is challenged by any person not a party to the Stipulation, the Stipulating
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.
STIPULATION AND SETTLEMENT- 16

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
If the Commission rejects any part or all of this Stipulation or imposes any
additional material conditions on approval of this Stipulation, each Stipulating 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.
The Stipulating Parties agree that this Stipulation is in the public interest and that
all of its terms and conditions are fair, just, and reasonable.
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
of regulation or cost recovery employed in arriving at this Stipulation is appropriate for
STIPULATION AND SETTLEMENT- 17

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
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.
The obligations of the Stipulating 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.
This Stipulation may be executed in counterparts and each signed counterpart
shall constitute an original document.
DATED this 24th day of October 2025.
Idaho Power Company Idaho Public Utilities Commission Staff
By By
Donovan Walker Erika Melanson
Attorney for Idaho Power Company Deputy Attorney General
Attorney for Commission Staff
City of Boise Clean Energy Opportunities for Idaho
B `d ,�c,wt,(,(, By kebey J.,e
y Kelsey Ed Jewell y Jae
Attorney for City of Boise Attorney for Clean Energy
Opportunities for Idaho
Federal Executive Agencies Idaho Irrigation Pumpers Association, Inc.
By �,►�/ �r�dGa� By C) c- �
Emily Medlyn Eric L. Olsen
Attorney for Federal Executive Attorney for Idaho Irrigation Pumpers
Agencies Association, Inc.
STIPULATION AND SETTLEMENT- 18

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Industrial Customers of Idaho Power Kroger Co.
By By 6wf 156L, A
Peter J. Richardson Kurt Boehm
Attorney for Industrial Customers Attorney for Kroger Inc.
of Idaho Power
Micron Technology, Inc. NW Energy Coalition
By QttiS �n ,SG�t�t b By
Austin Rueschhoff Benjamin J. Otto
Attorney for Micron Technology, Inc. Attorney for NW Energy Coalition
STIPULATION AND SETTLEMENT- 19

Industrial Customers of Idaho Power Kroger Co.
By Pam. By
Peter J. chardson Kurt Boehm
Attorney for Industrial Customers Attorney for Kroger Inc.
of Idaho Power
Micron Technology, Inc. NW Energy Coalition
By By
Austin Rueschhoff Benjamin J. Otto
Attorney for Micron Technology, Inc. Attorney for NW Energy Coalition
STIPULATION AND SETTLEMENT- 19

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
EXHIBIT NO. 1
RATE SPREAD

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Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
EXHIBIT NO. 2
PRICING

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service
Schedule 1 and Schedule 6
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 6,457,447 $ 15.00 $ 96,861,700 $ 15.00 $ 96,861,700
(2) Minimum Charge 37,059 3.00 111,178 3.00 111,178
(3) Summer Energy(Jun-Sep)
(4) First 800 kWh 1,290,839,001 $ 0.101779 $ 131,380,303 $ 0.121195 $ 156,443,233
(5) 801-2,000 kWh 551,835,102 0.122380 67,533,580 0.132995 73,391,309
(6) All Additional kWh 96,264,914 0.145385 13,995,475 0.146185 14,072,486
(7) Subtotal-Summer Energy 1,938,939,017 $ 0.109807 $ 212,909,357 $ 0.125794 $ 243,907,029
(8) Non-Summer Energy(Oct-May)
(9) First 800 kWh 2,563,878,153 $ 0.089569 $ 229,644,002 $ 0.099332 $ 254,675,145
(10) 801-2,000 kWh 1,035,332,377 0.098750 102,239,072 0.104305 107,990,344
(11) All Additional kWh 375,114,121 0.109361 41,022,855 0.110052 41,282,059
(12) Subtotal-Non-Summer Energy 3,974,324,652 $ 0.093829 $ 372,905,930 $ 0.101640 $ 403,947,548
(13) Subtotal-Total Energy 5,913,263,669 $ 585,815,287 $ 647,854,576
(14) Transfer Adjustment Revenue (4,994,462)
(15) Total Adjusted Base Revenue $ 677,793,704 $ 744,827,454
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 1 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service Standard Plan
Schedule 1
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 6,231,558 $ 15.00 $ 93,473,372 $ 15.00 $ 93,473,372
(2) Minimum Charge 36,602 3.00 109,807 3.00 109,807
(3) Summer Energy(Jun-Sep)
(4) First 800 kWh 1,252,168,857 $ 0.101779 $ 127,444,494 $ 0.121195 $ 151,756,605
(5) 801-2,000 kWh 541,234,863 0.122380 66,236,323 0.132995 71,981,531
(6) All Additional kWh 94,033,756 0.145385 13,671,098 0.146185 13,746,325
(7) Subtotal-Summer Energy 1,887,437,477 $ 0.109859 $ 207,351,914 $ 0.125824 $ 237,484,460
(8) Non-Summer Energy(Oct-May)
(9) First 800 kWh 2,492,142,872 $ 0.089569 $ 223,218,745 $ 0.099332 $ 247,549,536
(10) 801-2,000 kWh 1,006,802,014 0.098750 99,421,699 0.104305 105,014,484
(11) All Additional kWh 361,303,302 0.109361 39,512,490 0.110052 39,762,151
(12) Subtotal-Non-Summer Energy 3,860,248,188 $ 0.093816 $ 362,152,934 $ 0.101632 $ 392,326,171
(13) Subtotal-Total Energy 5,747,685,665 $ 569,504,849 $ 629,810,631
(14) Transfer Adjustment Revenue (4,854,611)
(15) Total Adjusted Base Revenue $ 658,233,416 $ 723,393,810
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 2 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service On-Site Generation
Schedule 6
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 225,889 $ 15.00 $ 3,388,329 $ 15.00 $ 3,388,329
(2) Minimum Charge 457 3.00 1,371 3.00 1,371
(3) Summer Energy(Jun-Sep)
(4) First 800 kWh 38,670,144 $ 0.101779 $ 3,935,809 $ 0.121195 $ 4,686,628
(5) 801-2,000 kWh 10,600,238 0.122380 1,297,257 0.132995 1,409,779
(6) All Additional kWh 2,231,158 0.145385 324,377 0.146185 326,162
(7) Subtotal-Summer Energy 51,501,540 $ 0.107908 $ 5,557,443 $ 0.124706 $ 6,422,569
(8) Non-Summer Energy(Oct-May)
(9) First 800 kWh 71,735,281 $ 0.089569 $ 6,425,257 $ 0.099332 $ 7,125,609
(10) 801-2,000 kWh 28,530,364 0.098750 2,817,373 0.104305 2,975,860
(11) All Additional kWh 13,810,819 0.109361 1,510,365 0.110052 1,519,908
(12) Subtotal-Non-Summer Energy 114,076,464 $ 0.094261 $ 10,752,996 $ 0.101874 $ 11,621,377
(13) Subtotal-Total Energy 165,578,004 $ 16,310,438 $ 18,043,945
(14) Transfer Adjustment Revenue (139,851)
(15) Total Adjusted Base Revenue $ 19,560,287 $ 21,433,645
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 3 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Master-Metered Mobile Home Park Residential Service
Schedule 3
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 225 $ 15.00 $ 3,374 $ 15.00 $ 3,374
(2) Total Energy 4,821,221 0.109482 527,837 0.119450 575,895
(3) Transfer Adjustment Revenue (4,072)
(4) Total Adjusted Base Revenue $ 527,138 $ 579,268
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 4 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service-Time-of-Use
Schedule 5+6 TOU
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 12,364 $ 15.00 $ 185,465 $ 15.00 $ 185,465
(2) Minimum Charge 7 3.00 21 3.00 21
(3) Summer Energy(Jun-Sep)
(4) On-Peak 1,047,143 $ 0.252957 $ 264,882 $ 0.299185 $ 313,289
(5) Mid-Peak 1,103,536 0.126480 139,575 0.149594 165,082
(6) Off-Peak 3,916,751 0.063241 247,699 0.074797 292,961
(7) Subtotal-Summer Energy 6,067,430 $ 0.107485 $ 652,157 $ 0.127128 $ 771,333
(8) Non-Summer Energy(Oct-May)
(9) On-Peak 2,841,379 $ 0.131150 $ 372,647 $ 0.138347 $ 393,096
(10) Off-Peak 9,653,346 0.087433 844,021 0.092231 890,338
(11) Subtotal-Non-Summer Energy 12,494,725 $ 0.097375 $ 1,216,668 $ 0.102718 $ 1,283,434
(12) Subtotal-Total Energy 18,562,155 $ 1,868,825 $ 2,054,767
(13) Transfer Adjustment Revenue (15,678)
(14) Total Adjusted Base Revenue $ 2,038,632 $ 2,240,253
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 5 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service-Time-of-Use Plan
Schedule 5
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 12,000 $ 15.00 $ 179,999 $ 15.00 $ 179,999
(2) Minimum Charge 6 3.00 18 3.00 18
(3) Summer Energy(Jun-Sep)
(4) On-Peak 1,033,452 $ 0.252957 $ 261,419 $ 0.299185 $ 309,193
(5) Mid-Peak 1,098,575 0.126480 138,948 0.149594 164,340
(6) Off-Peak 3,828,823 0.063241 242,139 0.074797 286,384
(7) Subtotal-Summer Energy 5,960,850 $ 0.107788 $ 642,505 $ 0.127485 $ 759,918
(8) Non-Summer Energy(Oct-May)
(9) On-Peak 2,788,557 $ 0.131150 $ 365,719 $ 0.138347 $ 385,789
(10) Off-Peak 9,421,467 0.087433 823,747 0.092231 868,951
(11) Subtotal-Non-Summer Energy 12,210,024 $ 0.097417 $ 1,189,466 $ 0.102763 $ 1,254,740
(12) Subtotal-Total Energy 18,170,875 $ 1,831,972 $ 2,014,658
(13) Transfer Adjustment Revenue (15,347)
(14) Total Adjusted Base Revenue $ 1,996,641 $ 2,194,675
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 6 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Residential Service-Time-of-Use
Schedule 6 TOU
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 364 $ 15.00 $ 5,466 $ 15.00 $ 5,466
(2) Minimum Charge 1 3.00 3 3.00 3
(3) Summer Energy(Jun-Sep)
(4) On-Peak 13,691 $ 0.252957 $ 3,463 $ 0.299185 $ 4,096
(5) Mid-Peak 4,961 0.126480 627 0.149594 742
(6) Off-Peak 87,928 0.063241 5,561 0.074797 6,577
(7) Subtotal-Summer Energy 106,580 $ 0.090555 $ 9,651 $ 0.107103 $ 11,415
(8) Non-Summer Energy(Oct-May)
(9) On-Peak 52,822 $ 0.131150 $ 6,928 $ 0.138347 $ 7,308
(10) Off-Peak 231,879 0.087433 20,274 0.092231 21,386
(11) Subtotal-Non-Summer Energy 284,700 $ 0.095544 $ 27,201 $ 0.100787 $ 28,694
(12) Subtotal-Total Energy 391,280 $ 36,853 $ 40,109
(13) Transfer Adjustment Revenue (330)
(14) Total Adjusted Base Revenue $ 41,991 $ 45,578
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 7 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Small General Service
Schedule 7 and Schedule 8
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 360,123 $ 25.00 $ 9,003,064 $ 25.00 $ 9,003,064
(2) Minimum Charge 217 3.00 651 3.00 651
(3) Summer Energy(Jun-Sep)
(4) First 300 kWh 21,542,878 $ 0.074534 $ 1,605,677 $ 0.087174 $ 1,877,979
(5) All Additional kWh 25,321,142 0.085176 2,156,754 0.099619 2,522,467
(6) Subtotal-Summer Energy 46,864,020 $ 0.080284 $ 3,762,430 $ 0.093898 $ 4,400,446
(7) Non-Summer Energy(Oct-May)
(8) First 300 kWh 44,450,246 $ 0.074534 $ 3,313,055 $ 0.087174 $ 3,874,906
(9) All Additional kWh 49,315,986 0.074552 3,676,605 0.087194 4,300,058
(10) Subtotal-Non-Summer Energy 93,766,231 $ 0.074543 $ 6,989,660 $ 0.087184 $ 8,174,964
(11) Subtotal-Total Energy 140,630,251 $ 10,752,090 $ 12,575,409
(12) Transfer Adjustment Revenue (118,779)
(13) Total Adjusted Base Revenue $ 19,637,026 $ 21,579,124
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 8 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Small General Service
Schedule 7
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 359,171 $ 25.00 $ 8,979,275 $ 25.00 $ 8,979,275
(2) Minimum Charge 217 3.00 651 3.00 651
(3) Summer Energy(Jun-Sep)
(4) First 300 kWh 21,488,093 $ 0.074534 $ 1,601,594 $ 0.087174 $ 1,873,203
(5) All Additional kWh 25,239,553 0.085176 2,149,804 0.099619 2,514,339
(6) Subtotal-Summer Energy 46,727,646 $ 0.080282 $ 3,751,398 $ 0.093896 $ 4,387,542
(7) Non-Summer Energy(Oct-May)
(8) First 300 kWh 44,361,036 $ 0.074534 $ 3,306,405 $ 0.087174 $ 3,867,129
(9) All Additional kWh 49,189,701 0.074552 3,667,191 0.087194 4,289,047
(10) Subtotal-Non-Summer Energy 93,550,738 $ 0.074543 $ 6,973,596 $ 0.087185 $ 8,156,176
(11) Subtotal-Total Energy 140,278,384 $ 10,724,994 $ 12,543,718
(12) Transfer Adjustment Revenue (118,482)
(13) Total Adjusted Base Revenue $ 19,586,437 $ 21,523,643
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 9 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Small General Service On-Site Generation
Schedule 8
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 952 $ 25.00 $ 23,789 $ 25.00 $ 23,789
(2) Minimum Charge - 3.00 - 3.00 -
(3) Summer Energy(Jun-Sep)
(4) First 300 kWh 54,785 $ 0.074534 $ 4,083 $ 0.087174 $ 4,776
(5) All Additional kWh 81,589 0.085176 6,949 0.099619 8,128
(6) Subtotal-Summer Energy 136,374 $ 0.080901 $ 11,033 $ 0.094620 $ 12,904
(7) Non-Summer Energy(Oct-May)
(8) First 300 kWh 89,209 $ 0.074534 $ 6,649 $ 0.087174 $ 7,777
(9) All Additional kWh 126,284 0.074552 9,415 0.087194 11,011
(10) Subtotal-Non-Summer Energy 215,494 $ 0.074545 $ 16,064 $ 0.087186 $ 18,788
(11) Subtotal-Total Energy 351,868 $ 27,097 $ 31,692
(12) Transfer Adjustment Revenue (297)
(13) Total Adjusted Base Revenue $ 50,589 $ 55,481
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 10 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large General Service
Schedule 9 Secondary Service-Standard (Default)
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 476,162 $ 25.00 $ 11,904,058 $ 25.00 $ 11,904,058
(2) Minimum Charge 267 3.00 800 3.00 800
(3) Basic Charge
(4) Total Basic Charge 15,707,257 $ 1.58 $ 24,817,466 $ 1.84 $ 28,901,353
(5) Demand Charge
(6) Summer(Jun-Sep) 4,157,240 $ 8.12 $ 33,756,793 $ 9.49 $ 39,452,212
(7) Non-Summer(Oct-May) 7,447,672 6.39 47,590,625 7.75 57,719,459
(8) Total Demand 11,604,913 $ 81,347,418 $ 97,171,671
(9) Energy Charge
(10) Summer(Jun-Sep) 1,204,197,234 $ 0.054658 $ 65,819,012 $ 0.050908 $ 61,303,273
(11) Non-Summer(Oct-May) 2,210,140,832 0.052721 116,520,835 0.049875 110,230,774
(12) Subtotal-Total Energy 3,414,338,066 $ 182,339,847 $ 171,534,047
(13) Transfer Adjustment Revenue (2,883,819)
(14) Total Adjusted Base Revenue $ 297,525,770 $ 309,511,929
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 11 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large General Service
Schedule 9 Secondary Service-Time-of-Use(Optional)
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 476,162 $ 25.00 $ 11,904,058 $ 25.00 $ 11,904,058
(2) Minimum Charge 267 3.00 800 3.00 800
(3) Basic Charge
(4) Total Basic Charge 15,707,257 $ 1.58 $ 24,817,466 $ 1.84 $ 28,901,353
(5) Demand Charge
(6) Summer(Jun-Sep) 4,157,240 $ 8.12 $ 33,756,793 $ 9.49 $ 39,452,212
(7) Non-Summer(Oct-May) 7,447,672 $ 6.39 47,590,625 7.75 57,719,459
(8) Total Demand 11,604,913 $ 81,347,418 $ 97,171,671
(9) Summer Energy(Jun-Sep)-Current
(10) On-Peak 165,592,662 $ 0.058489 $ 9,685,349
(11) Mid-Peak 238,482,029 0.058489 13,948,575
(12) Off-Peak 800,122,543 0.052709 42,173,659
(13) Subtotal-Summer Energy 1,204,197,234 $ 0.054649 $ 65,807,584
(14) Non-Summer Energy(Oct-Max)-Current
(15) On-Peak 483,916,916 $ 0.055755 $ 26,980,788
(16) Mid-Peak 521,990,534 0.053259 27,800,694
(17) Off-Peak 1,204,233,382 0.051273 61,744,658
(18) Subtotal-Non-Summer Energy 2,210,140,832 $ 0.052723 $ 116,526,140
(19) Subtotal-Total Energy 3,414,338,066 $ 182,333,723
(20) Summer Energy(Jun-Sep)-Proposed
(21) On-Peak 165,592,662 $ 0.064329 $ 10,652,410
(22) Mid-Peak 785,036,345 0.049542 38,892,271
(23) Off-Peak 253,568,226 0.046366 11,756,944
(24) Subtotal-Summer Energy 1,204,197,234 $ 0.050907 $ 61,301,625
(25) Non-Summer Energy(Oct-May)-Proposed
(26) On-Peak 483,916,916 $ 0.054425 $ 26,337,178
(27) Mid-Peak 1,362,166,169 0.049191 67,006,316
(28) Off-Peak 364,057,747 0.046375 16,883,178
(29) Subtotal-Non-Summer Energy 2,210,140,832 $ 0.049873 $ 110,226,672
(30) Subtotal-Total Energy 3,414,338,066 $ 171,528,298
(31) Transfer Adjustment Revenue (2,883,819)
(32) Total Adjusted Base Revenue $ 297,519,646 $ 309,506,180
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 12 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large General Service
Schedule 9 Primary Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 3,567 $ 340.00 $ 1,212,860 $ 345.00 $ 1,230,696
(2) Minimum Charge 3 50.00 150 50.00 150
(3) Basic Charge
(4) Total Basic Charge 2,039,979 $ 1.83 $ 3,733,162 $ 2.04 $ 4,161,558
(5) Demand Charge
(6) Summer(Jun-Sep) 467,927 $ 8.35 $ 3,907,194 $ 12.04 $ 5,633,846
(7) Non-Summer(Oct-May) 1,183,700 7.91 9,363,064 10.48 12,405,173
(8) Total Demand 1,651,627 $ 13,270,259 $ 18,039,019
(9) On-Peak Summer Demand (Jun-Sep) 463,301 $ 1.59 $ 736,648 $ 2.29 $ 1,060,959
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 32,583,784 $ 0.053937 $ 1,757,472
(12) Mid-Peak 45,744,926 0.053937 2,467,344
(13) Off-Peak 160,417,178 0.048346 7,755,529
(14) Subtotal-Summer Energy 238,745,888 $ 0.050180 $ 11,980,345
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 90,019,493 $ 0.048995 $ 4,410,505
(17) Mid-Peak 92,480,016 0.046579 4,307,627
(18) Off-Peak 218,953,648 0.044649 9,776,061
(19) Subtotal-Non-Summer Energy 401,453,157 $ 0.046068 $ 18,494,193
(20) Subtotal-Total Energy 640,199,045 $ 30,474,538
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 32,583,784 $ 0.053636 $ 1,747,664
(23) Mid-Peak 157,420,718 0.039840 6,271,641
(24) Off-Peak 48,741,386 0.036875 1,797,339
(25) Subtotal-Summer Energy 238,745,888 $ 0.041118 $ 9,816,644
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 90,019,493 $ 0.044679 $ 4,021,981
(28) Mid-Peak 247,328,559 0.039475 9,763,295
(29) Off-Peak 64,105,105 0.036674 2,350,991
(30) Subtotal-Non-Summer Energy 401,453,157 $ 0.040195 $ 16,136,266
(31) Subtotal-Total Energy 640,199,045 $ 25,952,910
(32) Transfer Adjustment Revenue (540,725)
(33) Total Adjusted Base Revenue $ 48,886,891 $ 50,445,292
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 13 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large General Service
Schedule 9 Transmission Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 77 $ 340.00 $ 26,166 $ 345.00 $ 26,550
(2) Minimum Charge - 50.00 - 50.00 -
(3) Basic Charge
(4) Total Basic Charge 38,534 $ 1.09 $ 42,002 $ 0.67 $ 25,818
(5) Demand Charge
(6) Summer(Jun-Sep) 10,689 $ 7.38 $ 78,887 $ 8.29 $ 88,614
(7) Non-Summer(Oct-May) 17,567 6.46 113,483 8.69 152,658
(8) Total Demand 28,256 $ 192,371 $ 241,272
(9) On-Peak Summer Demand (Jun-Sep) 5,890 $ 1.59 $ 9,364 $ 2.29 $ 13,487
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 216,999 $ 0.053305 $ 11,567
(12) Mid-Peak 309,876 0.053305 16,518
(13) Off-Peak 1,375,021 0.047648 65,517
(14) Subtotal-Summer Energy 1,901,896 $ 0.049215 $ 93,602
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 910,934 $ 0.048079 $ 43,797
(17) Mid-Peak 895,626 0.045663 40,897
(18) Off-Peak 2,476,174 0.043725 108,271
(19) Subtotal-Non-Summer Energy 4,282,734 $ 0.045056 $ 192,964
(20) Subtotal-Total Energy 6,184,630 $ 286,567
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 216,999 $ 0.056136 $ 12,181
(23) Mid-Peak 1,222,613 0.042114 51,489
(24) Off-Peak 462,284 0.039101 18,076
(25) Subtotal-Summer Energy 1,901,896 $ 0.042982 $ 81,746
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 910,934 $ 0.046703 $ 42,543
(28) Mid-Peak 2,516,092 0.041465 104,330
(29) Off-Peak 855,708 0.038647 33,071
(30) Subtotal-Non-Summer Energy 4,282,734 $ 0.042016 $ 179,944
(31) Subtotal-Total Energy 6,184,630 $ 261,690
(32) Transfer Adjustment Revenue (5,224)
(33) Total Adjusted Base Revenue $ 551,245 $ 568,817
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 14 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large Power Service
Schedule 19 Secondary Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 13 $ 85.00 $ 1,120 $ 110.00 $ 1,450
(2) Minimum Charge - 3.00 - 3.00 -
(3) Basic Charge
(4) Total Basic Charge 14,212 $ 2.01 $ 28,567 $ 2.27 $ 32,262
(5) Demand Charge
(6) Summer(Jun-Sep) 4,119 $ 10.50 $ 43,250 $ 14.46 $ 59,561
(7) Non-Summer(Oct-May) 8,368 8.45 70,707 13.05 109,198
(8) Total Demand 12,487 $ 113,956 $ 168,759
(9) On-Peak Summer Demand (Jun-Sep) 3,694 $ 1.82 $ 6,723 $ 2.51 $ 9,272
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 298,539 $ 0.059941 $ 17,895
(12) Mid-Peak 378,317 0.059941 22,677
(13) Off-Peak 1,390,942 0.054287 75,510
(14) Subtotal-Summer Energy 2,067,798 $ 0.056138 $ 116,081
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 861,406 $ 0.054204 $ 46,692
(17) Mid-Peak 890,197 0.051783 46,097
(18) Off-Peak 2,228,865 0.049842 111,091
(19) Subtotal-Non-Summer Energy 3,980,468 $ 0.051220 $ 203,880
(20) Subtotal-Total Energy 6,048,266 $ 319,961
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 298,539 $ 0.059565 $ 17,782
(23) Mid-Peak 1,370,910 0.045019 61,717
(24) Off-Peak 398,349 0.041894 16,688
(25) Subtotal-Summer Energy 2,067,798 $ 0.046517 $ 96,188
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 861,406 $ 0.049879 $ 42,966
(28) Mid-Peak 2,512,550 0.044723 112,369
(29) Off-Peak 606,512 0.041950 25,443
(30) Subtotal-Non-Summer Energy 3,980,468 $ 0.045416 $ 180,778
(31) Subtotal-Total Energy 6,048,266 $ 276,966
(32) Transfer Adjustment Revenue (5,108)
(33) Total Adjusted Base Revenue $ 465,220 $ 488,709
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 15 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large Power Service
Schedule 19 Primary Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 1,624 $ 415.00 $ 674,104 $ 450.00 $ 730,956
(2) Minimum Charge - 50.00 - 50.00 -
(3) Basic Charge
(4) Total Basic Charge 4,997,899 $ 2.21 $ 11,045,356 $ 2.32 $ 11,595,125
(5) Demand Charge
(6) Summer(Jun-Sep) 1,490,176 $ 10.04 $ 14,961,364 $ 13.51 $ 20,132,273
(7) Non-Summer(Oct-May) 2,924,469 8.64 25,267,414 12.68 37,082,270
(8) Total Demand 4,414,645 $ 40,228,778 $ 57,214,543
(9) On-Peak Summer Demand (Jun-Sep) 1,328,154 $ 1.59 $ 2,111,764 $ 2.14 $ 2,842,249
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 105,332,662 $ 0.052314 $ 5,510,373
(12) Mid-Peak 136,006,423 0.052314 7,115,040
(13) Off-Peak 498,834,125 0.046655 23,273,106
(14) Subtotal-Summer Energy 740,173,209 $ 0.048500 $ 35,898,519
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 314,955,889 $ 0.047227 $ 14,874,422
(17) Mid-Peak 318,731,217 0.044805 14,280,752
(18) Off-Peak 816,258,432 0.042863 34,987,285
(19) Subtotal-Non-Summer Energy 1,449,945,538 $ 0.044238 $ 64,142,459
(20) Subtotal-Total Energy 2,190,118,747 $ 100,040,978
(21) Subtotal 19P Excluding Clean Energy Your Way $ 154,100,980
(22) Summer Energy(Jun-Sep)-Proposed
(23) On-Peak 105,332,662 $ 0.053694 $ 5,655,732
(24) Mid-Peak 496,428,762 0.039145 19,432,704
(25) Off-Peak 138,411,785 0.036018 4,985,316
(26) Subtotal-Summer Energy 740,173,209 $ 0.040631 $ 30,073,752
(27) Non-Summer Energy(Oct-May)-Proposed
(28) On-Peak 314,955,889 $ 0.044112 $ 13,893,334
(29) Mid-Peak 920,912,295 0.038960 35,878,743
(30) Off-Peak 214,077,354 0.036187 7,746,817
(31) Subtotal-Non-Summer Energy 1,449,945,538 $ 0.039670 $ 57,518,894
(32) Subtotal-Total Energy 2,190,118,747 $ 87,592,646
(33) Subtotal 19P Excluding Clean Energy Your Way $ 159,975,519
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 16 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large Power Service
Schedule 19 Primary Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(34) Schedule 62 Clean Energy Your Way-Optional
(35) Summer Embedded Energy Fixed Cost (June-Sep)
(36) On-Peak 1,299,249 $ 0.010012 $ 13,008 $ 0.012551 $ 16,307
(37) Mid-Peak 3,459,015 0.010012 34,632 0.012551 43,414
(38) Off-Peak 1,288,171 0.009611 12,381 0.012551 16,168
(39) Subtotal-Summer Embedded Energy Fixed C 6,046,435 $ 0.009927 $ 60,020 $ 0.012551 $ 75,889
(40) Non-Summer Embedded Energy Fixed Cost (Oct-May)
(41) On-Peak 1,996,175 $ 0.018270 $ 36,470 $ 0.012254 $ 24,461
(42) Mid-Peak 3,575,615 0.018130 64,826 0.012254 43,816
(43) Off-Peak 1,772,649 0.018018 31,940 0.012254 21,722
(44) Subtotal-Non-Summer Embedded Energy Fix 7,344,440 $ 0.018141 $ 133,236 $ 0.012254 $ 89,999
(45) Subtotal-Total Embedded Energy Fixed Cost 13,390,875 $ 193,256 $ 165,888
(46) Transfer Adjustment Revenue (1,849,818)
(47) Total Adjusted Base Revenue $ 152,444,418 $ 160,141,407
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 17 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Large Power Service
Schedule 19 Transmission Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 34 $ 415.00 $ 14,178 $ 450.00 $ 15,374
(2) Minimum Charge - 50.00 - 50.00 -
(3) Basic Charge
(4) Total Basic Charge 71,485 $ 1.87 $ 133,676 $ 1.16 $ 82,922
(5) Demand Charge
(6) Summer(Jun-Sep) 19,497 $ 10.20 $ 198,868 $ 15.19 $ 296,157
(7) Non-Summer(Oct-May) 41,449 8.78 363,923 13.37 554,174
(8) Total Demand 60,946 $ 562,790 $ 850,331
(9) On-Peak Summer Demand (Jun-Sep) 14,790 $ 1.59 $ 23,516 $ 2.14 $ 31,651
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 1,335,421 $ 0.052142 $ 69,632
(12) Mid-Peak 1,693,103 0.052142 88,282
(13) Off-Peak 7,157,157 0.046451 332,457
(14) Subtotal-Summer Energy 10,185,681 $ 0.048143 $ 490,370
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 4,763,451 $ 0.046927 $ 223,534
(17) Mid-Peak 4,769,702 0.044504 212,271
(18) Off-Peak 12,526,659 0.042561 533,147
(19) Subtotal-Non-Summer Energy 22,059,811 $ 0.043924 $ 968,952
(20) Subtotal-Total Energy 32,245,493 $ 1,459,323
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 1,335,421 $ 0.054173 $ 72,344
(23) Mid-Peak 6,849,229 0.039529 270,743
(24) Off-Peak 2,001,031 0.036381 72,799
(25) Subtotal-Summer Energy 10,185,681 $ 0.040830 $ 415,886
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 4,763,451 $ 0.044324 $ 211,135
(28) Mid-Peak 13,991,496 0.039169 548,033
(29) Off-Peak 3,304,865 0.036395 120,281
(30) Subtotal-Non-Summer Energy 22,059,811 $ 0.039867 $ 879,449
(31) Subtotal-Total Energy 32,245,493 $ 1,295,335
(32) Transfer Adjustment Revenue (27,235)
(33) Total Adjusted Base Revenue $ 2,166,248 $ 2,275,612
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 18 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Agricultural Irrigation Service
Schedule 24 Secondary Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Current Season-Meter Read Cycle
(2) Service Charge In-Season 78,236 $ 30.00 $ 2,347,087
(3) Service Charge Out-of-Season 157,992 6.00 947,949
(4) Minimum Charge 621 3.00 1,862
(5) Demand Charge(Current Season)
(6) In-Season 3,975,361 $ 15.06 $ 59,868,937
(7) Out-of-Season - - -
(8) Energy Charge(Current Season)
(9) In-Season 1,490,396,996 $ 0.061295 $ 91,353,884
(10) Out-of-Season 347,772,454 0.072053 25,058,049
(11) Total Energy 1,838,169,450 $ 116,411,932
(12) Proposed Season-Calendar Month
(13) Service Charge In-Season 80,992 $ 35.00 $ 2,834,710
(14) Service Charge Out-of-Season 155,236 9.00 1,397,124
(15) Minimum Charge 621 3.00 1,862
(16) Demand Charge(Proposed Season)
(17) In-Season 3,896,929 $ 16.50 $ 64,299,326
(18) Out-of-Season - - -
(19) Energy Charge(Proposed Season)
(20) In-Season 1,443,146,046 $ 0.067222 $ 97,011,164
(21) Out-of-Season 394,992,435 0.070752 27,946,505
(22) Total Energy 1,838,138,482 $ 124,957,668
(23) Transfer Adjustment Revenue (1,552,555)
(24) Total Adjusted Base Revenue $ 178,025,213 $ 193,490,690
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 19 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Agricultural Irrigation Service
Schedule 24 Transmission Service
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge In-Season - $ 415.00 $ - $ 450.00 $ -
(2) Service Charge Out-of-Season - 6.00 - 9.00 -
(3) Minimum Charge - 3.00 - 3.00 -
(4) Demand Charge
(5) In-Season - $ 13.92 $ - $ 15.25 $ -
(6) Out-of-Season - - -
(7) Energy Charge
(8) In-Season - $ 0.057529 $ - $ 0.063092 $ -
(9) Out-of-Season - 0.067352 - 0.066136 -
(10) Total Energy - $ - $ -
(11) Transfer Adjustment Revenue -
(12) Total Adjusted Base Revenue $ - $ -
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 20 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Dusk to Dawn Customer Lighting
Schedule 15
Column (A) (B) (C) (D) (E) (F)
Current Test Year Proposed Proposed
Line Annual Base Base Effective Effective
No. Description Lamps Rate Revenue Rate Revenue
(1) Lamps
(2) Area Lighting
(3) 40 Watt Max 87,846 $ 9.82 $ 862,652 $ 10.95 $ 961,918
(4) 85 Watt Max 9,574 11.95 114,406 11.67 111,725
(5) 200 Watt Max 1,780 17.27 30,737 14.38 25,593
(6) Subtotal-Lamps $ 1,007,795
(7) Flood Lighting
(8) 85 Watt Max 16,494 $ 19.50 $ 321,623 $ 16.14 $ 266,205
(9) 150 Watt Max 436 21.47 9,361 17.03 7,425
(10) 300 Watt Max 1,129 25.28 28,539 22.42 25,311
(11) Subtotal-Lamps $ 359,524
(12) Transfer Adjustment Revenue (1,634)
(13) Total Adjusted Base Revenue $ 1,365,685 1,398,178
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 21 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Non-Metered General Service
Schedule 40
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 22,449 $ - $ - $ - $
(2) Minimum Bills 1,179 2.00 2,359 2.00 2,359
(3) Total Energy 14,544,979 0.100058 1,455,342 0.103710 1,508,460
(4) Intermittent Usage 156 2.00 312 2.50 390
(5) Transfer Adjustment Revenue (12,285)
(6) Total Adjusted Base Revenue $ 1,445,727 $ 1,511,209
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 22 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Street Lighting Service
Schedule 41 -Summary
Column (A) (B) (C) (D)
Test Year Proposed
Line Test Year Base Effective
No. Description Usage Revenue Revenue
(1) A-Company-Owned, Non-Metered, Maintenai 2,308,188 $ 2,632,419 $ 3,344,753
(2) C-Customer-Owned, Non-Metered, No Maini 11,829,043 803,310 443,518
(3) CM-Customer-Owned, Metered, No Maintene 6,677,084 561,194 285,626
(4) Total kWh 20,814,315
(5) Transfer Adjustment Revenue $ (17,580)
(6) Total Adjusted Base Revenue $ 3,979,343 $ 4,073,897
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 23 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Street Lighting Service
A-Company-Owned, Non-Metered, Maintenance
Column (A) (B) (C) (D) (E) (F)
Current Test Year Proposed Proposed
Line Annual Base Base Effective Effective
No. Description Lamps Rate Revenue Rate Revenue
(7) LED Fixture
(8) 40W Max 183,274 $ 12.30 $ 2,254,265 $ 15.84 $ 2,903,053
(9) 85W Max 20,345 14.31 291,133 $ 17.05 346,878
(10) 140W Max 2,726 16.43 44,791 $ 18.54 50,543
(11) 200W Max 1,853 20.44 37,879 $ 21.46 39,769
(12) Total LED 208,198 $ 2,628,067 $ 3,340,243
(13) Non-Metered-Variable Energy Use 43,492 $ 0.100058 $ 4,352 $ 0.103710 $ 4,511
(14) A-Company-Owned, Non-Metered, Maintenance $ 2,632,419 $ 3,344,753
NM Adi
$ 0.021665
C-Customer-Owned, Non-Metered, No Maintenance
Current Test Year Proposed Proposed
Line Test Year Base Base Effective Effective
No. Description Usage Rate Revenue Rate Revenue
(15) Energy Charge
(16) Per kWh 11,829,043 $ 0.067910 $ 803,310 $ 0.037494 $ 443,518
(17) C-Customer-Owned, Non-Metered, No Maintenance $ 803,310 $ 443,518
CM-Customer-Owned, Metered, No Maintenance
Current Test Year Proposed Proposed
Line Test Year Base Base Effective Effective
No. Description Usage Rate Revenue Rate Revenue
(18) Service Charge per Meter 19,276 $ 5.59 $ 107,753 $ 1.83 $ 35,275
(19) Energy Charge
(20) Per kWh 6,677,084 $ 0.067910 $ 453,441 $ 0.037494 $ 250,351
(21) CM-Customer-Owned, Metered, No Maintenance $ 561,194 $ 285,626
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 24 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Traffic Control Signal Lighting Service
Schedule 42
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Service Charge 4,295 $ - $ - $ - $
(2) Total Energy 3,125,463 0.078462 245,230 0.085293 266,580
(3) Transfer Adjustment Revenue (2,640)
(4) Total Adjusted Base Revenue $ 242,590 $ 266,580
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 25 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Micron Technology, Inc.
Schedule 26
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Contract Demand 1,062,000 $ 3.37 $ 3,578,940 $ 3.12 $ 3,313,440
(2) Billing Demand 971,293 17.83 17,318,159 21.04 20,436,010
(3) Excess Demand - 1.288 - 1.248 -
(4) Embedded Energy Fixed Cost - - - - -
(5) Total Energy 599,124,265 $ 0.030394 18,209,783 $ 0.027165 16,275,211
(6) Transfer Adjustment Revenue (506,032)
(7) Total Adjusted Base Revenue $ 38,600,849 $ 40,024,661
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 26 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
J.R.Simplot Company-Pocatello
Schedule 29
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Contract Demand 300,000 $ 3.25 $ 975,000 $ 3.12 $ 936,000
(2) Billing Demand 290,903 14.80 4,305,358 17.41 5,064,614
(3) Excess Demand - 1.267 - 1.248 -
(4) Total Energy 169,812,387 0.031006 5,265,203 0.027377 4,648,954
(5) Transfer Adjustment Revenue (143,427)
(6) Total Adjusted Base Revenue $ 10,402,134 $ 10,649,568
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 27 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
United States Department of Energy
Schedule 30
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Contract Demand
(2) Billing Demand 387,060 $ 10.17 $ 3,936,404 $ 14.49 $ 5,608,504
(3) Excess Demand
(4) Total Energy 214,503,623 $ 0.042488 $ 9,113,830 0.037699 $ 8,086,572
(5) Transfer Adjustment Revenue (181,174)
(6) Total Adjusted Base Revenue $ 12,869,059 $ 13,695,076
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 28 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
J.R.Simplot Company-Caldwell
Schedule 32
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Contract Demand
(2) Summer 100,000 $ 3.30 $ 330,000 $ 3.12 $ 312,000
(3) Non-Summer 200,000 3.30 660,000 3.12 624,000
(4) Billing Demand
(5) Summer 86,462 $ 19.60 $ 1,694,664 $ 22.11 $ 1,911,685
(6) Non-Summer 162,474 16.20 2,632,080 20.17 3,277,102
(7) Excess Demand
(8) Summer - $ 1.293 $ - $ 1.248 $ -
(9) Non-Summer - 1.293 - 1.248 -
(10) Energy
(11) Summer 51,609,967 $ 0.030405 $ 1,569,201 $ 0.027520 $ 1,420,306
(12) Non-Summer 97,127,610 0.032844 3,190,059 0.027202 2,642,065
(13) Transfer Adjustment Revenue (125,627)
(14) Total Adjusted Base Revenue $ 9,950,378 $ 10,187,158
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 29 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Brisbie,LLC.
Schedule 33
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Block 1
(2) Service Charge 10 $ 415.00 $ 4,150 $ 450.00 $ 4,500
(3) Basic Charge
(4) Total Basic Charge 200,000 $ 1.87 $ 374,000 $ 1.16 $ 232,000
(5) Demand Charges
(6) Summer(Jun-Sep) 80,000 $ 10.20 $ 816,000 $ 15.19 $ 1,215,200
(7) Non-Summer(Oct-May) 120,000 8.78 1,053,600 13.37 1,604,400
(8) Total Demand 200,000 $ 1,869,600 $ 2,819,600
(9) On-Peak Summer Demand (Jun-Sep) 7,632 $ 1.59 $ 12,135 $ 2.14 $ 16,332
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 186,309 $ 0.052142 $ 9,715
(12) Mid-Peak 110,052 0.052142 5,738
(13) Off-Peak 904,321 0.046451 42,007
(14) Subtotal-Summer Energy 1,200,682 $ 57,459
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 3,486 $ 0.046927 $ 164
(17) Mid-Peak 10,047 0.044504 447
(18) Off-Peak 124,439 0.042561 5,296
(19) Subtotal-Non-Summer Energy 137,972 $ 5,907
(20) Subtotal-Total Energy 1,338,655 63,366
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 186,309 $ 0.054173 $ 10,093
(23) Mid-Peak 819,158 0.039529 32,380
(24) Off-Peak 195,216 0.036381 7,102
(25) Subtotal-Summer Energy 1,200,682 $ 0.041289 $ 49,576
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 3,486 $ 0.044324 $ 155
(28) Mid-Peak 111,474 0.039169 4,366
(29) Off-Peak 23,012 0.036395 838
(30) Subtotal-Non-Summer Energy 137,972 $ 0.038837 $ 5,358
(31) Subtotal-Total Energy 1,338,655 $ 54,934
(32) Subtotal 33 Excluding Clean Energy Your Way $ 3,127,366
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 30 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Brisbie,LLC.
Schedule 33
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(33) Schedule 62 Clean Energy Your Way-Optional
(34) Summer Embedded Energy Fixed Cost (June-Sep)
(35) On-Peak 275,535 $ 0.010007 $ 2,757 $ 0.012752 $ 3,514
(36) Mid-Peak 570,564 0.010007 5,710 0.012752 7,276
(37) Off-Peak 2,331,719 0.009603 22,391 0.012752 29,734
(38) Subtotal-Summer Embedded Energy Fixed C 3,177,818 $ 30,858 $ 0.012752 $ 40,524
(39) Non-Summer Embedded Energy Fixed Cost (Oct-May)
(40) On-Peak 76,707 $ 0.018257 $ 1,400 $ 0.012451 $ 955
(41) Mid-Peak 81,188 0.018117 1,471 0.012451 1,011
(42) Off-Peak 107,934 0.018005 1,943 0.012451 1,344
(43) Subtotal-Non-Summer Embedded Energy Fix 265,829 $ 4,815 $ 0.012451 $ 3,310
(44) Subtotal-Total Embedded Energy Fixed Cost 3,443,646 35,673 $ 43,833
(45) Subtotal-Block 1 $ 2,358,924 $ 3,171,200
(46) Block 2
(47) Contract Demand 100,000 $ 3.28 $ 328,000 $ 3.12 $ 312,000
(48) Billing Demand - 22.29 - 22.29 -
(49) Excess Demand 1.293 - 1.248 -
(50) Subtotal-Block 2 $ 328,000 $ 312,000
(51) Transfer Adjustment Revenue - -
(52) Total Adjusted Base Revenue $ 2,686,924 $ 3,483,200
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 31 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Lamb Weston,Inc.
Schedule 34
Column (A) (B) (C) (D) (E) (F)
Test Year Current Test Year Proposed Proposed
Line Billing Base Base Effective Effective
No. Description Units Rate Revenue Rate Revenue
(1) Block 1
(2) Service Charge 12 $ 415.00 $ 4,980 $ 450.00 $ 5,400
(3) Basic Charge
(4) Total Basic Charge 243,474 $ 2.21 $ 538,078 $ 2.32 $ 564,860
(5) Demand Charges
(6) Summer(Jun-Sep) 80,000 $ 10.04 $ 803,200 $ 13.51 $ 1,080,800
(7) Non-Summer(Oct-May) 160,000 8.64 1,382,400 $ 12.68 2,028,800
(8) Total Demand $ 2,185,600 $ 3,109,600
(9) On-Peak Summer Demand (Jun-Sep) 73,876 $ 1.59 $ 117,463 $ 2.14 $ 158,095
(10) Summer Energy(Jun-Sep)-Current
(11) On-Peak 5,890,298 $ 0.052314 $ 308,145
(12) Mid-Peak 7,514,127 0.052314 393,094
(13) Off-Peak 27,742,320 0.046655 1,294,318
(14) Subtotal-Summer Energy 41,146,744 $ 1,995,557
(15) Non-Summer Energy(Oct-May)-Current
(16) On-Peak 16,729,387 $ 0.047227 $ 790,079
(17) Mid-Peak 16,625,725 0.044805 744,916
(18) Off-Peak 44,705,115 0.042863 1,916,195
(19) Subtotal-Non-Summer Energy 78,060,227 $ 3,451,190
(20) Subtotal-Total Energy 119,206,972 5,446,747
(21) Summer Energy(Jun-Sep)-Proposed
(22) On-Peak 5,890,298 $ 0.051897 $ 305,689
(23) Mid-Peak 28,187,170 0.037373 1,053,439
(24) Off-Peak 7,069,276 0.034253 242,144
(25) Subtotal-Summer Energy 41,146,744 $ 0.038916 $ 1,601,272
(26) Non-Summer Energy(Oct-Max)-Proposed
(27) On-Peak 16,729,387 $ 0.042438 $ 709,962
(28) Mid-Peak 50,203,403 0.037285 1,871,834
(29) Off-Peak 11,127,437 0.034513 384,041
(30) Subtotal-Non-Summer Energy 78,060,227 $ 0.037994 $ 2,965,837
(31) Subtotal-Total Energy 119,206,972 4,567,109
(32) Subtotal-Block 1 $ 8,292,867 $ 8,405,063
(33) Block 2
(34) Contract Demand 48,000 $ 3.30 $ 158,400 $ 3.12 $ 149,760
(35) Billing Demand 9,556 24.19 231,149 24.19 231,149
(36) Excess Demand 1.293 - 1.248 -
(37) Subtotal-Block 2 $ 389,549 $ 380,909
(38) Transfer Adjustment Revenue (100,685) -
(39) Total Adjusted Base Revenue $ 8,581,731 $ 8,785,972
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 32 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Schedule 9P Schedule 20 Large General Service Primary Rates-Proposed
Charge Type Charge Type
Service Charge(per customer) $ 345.00 $ 345.00 Service Charge(per customer) $ 345.00 $ 345.00
Basic Charge per kW of BLC $ 2.04 $ 2.04 Basic Charge per kW of BLC $ 2.04 $ 2.04
Demand Charge per kW $ 12.04 $ 10.48 (rate+b) Demand Charge per kW $ 12.68 $ 11.12
On-Peak Demand charge per kW $ 2.29 n/a On-Peak Demand charge per kW n/a n/a
On Peak Energy Charge per kWh $ 0.053636 $ 0.044679 (rate-c+a) On Peak Energy Charge per kWh $ 0.079058 $ 0.066122
Mid Peak Energy Charge per kWh $ 0.039840 $ 0.039475 (rate-c+a) Mid Peak Energy Charge per kWh is 0.061266 1 $ 0.053736
Off Peak Energy Charge per kWh $ 0.036875 $ 0.036674 (rate-c+a) Off Peak Energy Charge per kWh I$ 0.045473 1 $ 0.047482
Schedule 9T Schedule 20 Large General Service Transmission Rates-Proposed
Charge Type Charge Type Summer Non-Summer
Service Charge(per customer) $ 345.00 $ 345.00 Service Charge(per customer) $ 345.00 $ 345.00
Basic Charge per kW of BLC $ 0.67 $ 0.67 Basic Charge per kW of BLC $ 0.67 $ 0.67
Demand Charge per kW $ 8.29 $ 8.69 (rate+b) Demand Charge per kW $ 8.93 $ 9.33
On-Peak Demand charge per kW $ 2.29 n/a On-Peak Demand charge per kW n/a n/a
On Peak Energy Charge per kWh $ 0.056136 $ 0.046703 (rate-c+a) On Peak Energy Charge per kWh $ 0.081558 $ 0.068146
Mid Peak Energy Charge per kWh $ 0.042114 $ 0.041465 (rate-c+a) Mid Peak Energy Charge per kWh $ 0.063540 $ 0.055726
Off Peak Energy Charge per kWh $ 0.039101 $ 0.038647 (rate-c+a) Off Peak Energy Charge per kWh $ 0.047699 $ 0.049455
(a) Marginal Cost($/kWh) S INS
On-Peak $ 0.052673 $ 0.048694
Mid-Peak $ 0.048677 $ 0.041512
Off-Peak $ 0.035849 $ 0.038059
...........................................
(b) Peak Demand Adder($/kW) $ 0.64
..........................................
...........................................
(c) Embedded Energy Rate($/kWh) $ 0.027251
..........................................
...........................................
(d) Interruption Compensation $ 0.0453
:.........................................:
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 33 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Schedule 19P Schedule 20 Large Power Primary Rates-Proposed
Charge Type Charge Type
Service Charge(per customer) $ 450.00 $ 450.00 Service Charge(per customer) $ 450.00 $ 450.00
Basic Charge per kW of BLC $ 2.32 $ 2.32 Basic Charge per kW of BLC $ 2.32 $ 2.32
Demand Charge per kW $ 13.51 $ 12.68 (rate+b) Demand Charge per kW $ 14.15 $ 13.32
On-Peak Demand charge per kW $ 2.14 n/a On-Peak Demand charge per kW n/a n/a
On Peak Energy Charge per kWh $ 0.053694 $ 0.044112 (rate-c+a) On Peak Energy Charge per kWh $ 0.078652 $ 0.065091
Mid Peak Energy Charge per kWh $ 0.039145 $ 0.038960 (rate-c+a) Mid Peak Energy Charge per kWh is 0.060107 1 $ 0.052757
Off Peak Energy Charge per kWh $ 0.036018 $ 0.036187 (rate-c+a) Off Peak Energy Charge per kWh I$ 0.044152 1 $ 0.046531
Schedule 19T Schedule 20 Large Power Transmission Rates-Proposed
Charge Type Charge Type Summer Non-Summer
Service Charge(per customer) $ 450.00 $ 450.00 Service Charge(per customer) $ 450.00 $ 450.00
Basic Charge per kW of BLC $ 1.16 $ 1.16 Basic Charge per kW of BLC $ 1.16 $ 1.16
Demand Charge per kW $ 15.19 $ 13.37 (rate+b) Demand Charge per kW $ 15.83 $ 14.01
On-Peak Demand charge per kW $ 2.14 n/a On-Peak Demand charge per kW n/a n/a
On Peak Energy Charge per kWh $ 0.054173 $ 0.044324 (rate-c+a) On Peak Energy Charge per kWh $ 0.079131 $ 0.065303
Mid Peak Energy Charge per kWh $ 0.039529 $ 0.039169 (rate-c+a) Mid Peak Energy Charge per kWh $ 0.060491 $ 0.052966
Off Peak Energy Charge per kWh $ 0.036381 $ 0.036395 (rate-c+a) Off Peak Energy Charge per kWh $ 0.044515 $ 0.046739
(a) Marginal Cost($/kWh) S INS
On-Peak $ 0.052673 $ 0.048694
Mid-Peak $ 0.048677 $ 0.041512
Off-Peak $ 0.035849 $ 0.038059
...........................................
(b) Peak Demand Adder($/kW) $ 0.64
..........................................
...........................................
(c) Embedded Energy Rate($/kWh) $ 0.027715
..........................................
...........................................
(d) Interruption Compensation $ 0.0451
:..........................................
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 34 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Amalgamated Standby Agreement
Schedule 31A
Column (A) (B) (C) (D)
Line Unit Cost,
No. Description Total Cost Billing Units per kW
(1) Standby Contract Demand Charge, per kW $ 3.12
(2) Generation Capacity(Non-summer) $ 42,970,620 2,974,286 $ 14.45
(3) Transmission Capacity 13,607,639 4,488,077 3.03
(4) Distribution Capacity
(5) Substation $ 5,239,049 4,488,077 $ 1.17
(6) Primary Lines 8,208,139 4,488,077 1.83
(7) Primary Line Trans. 1,112,458 4,488,077 0.25
(8) Total Standby Demand Component $ 20.72
(9) Ratio of$12.68 to$20.34(Note 1) 0.6233
(10) Standby Demand Component $ 12.92
(11) Less: Standby Reservation Charge (5.98)
(12) Standby Billing Demand Charge, per kW $ 6.93
Note 1: Proposed non-summer demand charge for Schedule 19P is$12.68. Sum of total of generation,
transmission, and distribution components is$20.34.
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 35 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Amalgamated Standby Agreement
Schedule 31 B
Column (A) (B)
Line Unit Cost,
No. Description per kW
(1) Standby Facilities Contract Demand Charge
(2) Paul Facility $ 2.72
(3) Nampa Facility $ 2.74
(4) Twin Falls Facility $ 2.39
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 36 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
DERIVATION OF STANDBY RESERVATION CHARGES-SCHEDULE 9
Standby Standby Standby
Reservation Reservation Reservation
Unit Cost, Charge Charge Charge
per kW Primary Transmission Secondary
Generation&Transmission Standby Reservation Component
1 Open Access Transmission Tariff $3.12 $3.12 $3.12 $3.12
Distribution Reserve Component Rev. Reg. Billing Units
Schedule 9P
2 Schedule 9P Substation $ 1,985,008 2,078,513 $0.95501 $0.96
3 Schedule 9P Primary Lines 3,106,780 2,078,513 $1.49471 $1.49
4 Schedule 9P Primary Trans. 421,689 2,078,513 $0.20288 $0.20
5 Schedule 9P Dist.Subtotal $5,513,477 2,078,513 $2.65261 $2.65
Schedule 9S
6 Schedule 9S Substation $ 11,323,901 15,707,257 $0.72093 $0.72
7 Schedule 9S Primary Lines 17,688,591 15,707,257 $1.12614 $1.13
8 Schedule 9S Primary Trans. 2,407,722 15,707,257 $0.15329 $0.15
9 Schedule 9S Secondary Lines 1,492,603 15,707,257 $0.09503 $0.10
10 Schedule 9S Secondary Trans. 7,913,994 15,707,257 $0.50384 $0.50
11 Schedule 9S Dist. Subtotal $40,826,811 15,707,257 $2.59923 $2.60
Schedule 45 Standby Reservation Charge
12 Total $5.77 $3.12 $5.72
DERIVATION OF STANDBY DEMAND CHARGES-SCHEDULE 9
Standby Standby Standby
Demand Demand Demand
Unit Cost, Charge Charge Charge
Rev. Reg. Billing Units per kW Primary Transmission Secondary
Generation Demand Component
Schedule 9P&9T
13 Summer $ 8,095,767 478,617 $16.91493 $16.91 $16.91
14 Non-Summer $ 13,064,937 1,201,267 $10.87597 $10.88 $10.88
Schedule 9S
15 Summer $ 46,791,824 4,157,240 $11.25550 $11.26
16 Non-Summer $ 72,599,896 7,447,672 $9.74800 $9.75
Transmission Demand Component
17 Schedule 9P&9T $ 4,313,081 1,679,884 $2.56749 $2.57 $2.57
18 Schedule 9S 25,027,351 11,604,913 $2.15662 $2.16
Distribution Demand Component
19 Schedule 9P Dist.Subtotal $5,513,477 2,078,513 $2.65261 $2.65
20 Schedule 9S Dist. Subtotal $40,826,811 15,707,257 $2.59923 $2.60
Schedule 45 Total Demand Component
Schedule 9P&9T
21 Summer $22.14 $19.48
22 Non-Summer $16.10 $13.44
Schedule 9S
23 Summer $16.01
24 Non-Summer $14.50
25 Ratio of Sch. 9P/COS; S $12.04 $19.48250 0.61799
26 Ratio of Sch. 9P/COS; NS $10.48 $13.44354 0.77956
27 Ratio of Sch. 9T/COS; S $8.29 $19.48250 0.42551 Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 37 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
28 Ratio of Sch. 9T/COS; NS $8.69 $13.44354 0.64641
29 Ratio of Sch. 9S/COS; S $9.49 $13.41212 0.70757
30 Ratio of Sch. 9S/COS; NS $7.75 $11.90462 0.65101
Schedule 45 Standby Demand Charge
31 Summer $13.68 $8.29 $11.33
32 Non-Summer $12.55 $8.69 $9.44
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 38 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
DERIVATION OF STANDBY RESERVATION CHARGES-SCHEDULE 19
Standby Standby
Reservation Reservation
Unit Cost, Charge Charge
per kW Primary Transmission
Generation&Transmission Standby Reservation Component
1 Open Access Transmission Tariff $3.12 $3.12 $3.12
Unit Cost,
Distribution Reserve Component Rev.Reg. Billing Units per kW
2 Schedule 19P Substation $ 5,239,049 5,083,596 $1.03058 $1.03
3 Schedule 19P Primary Lines $ 8,208,139 5,083,596 $1.61463 $1.61
4 Schedule 19P Primary Trans. $1,112,458 5,083,596 $0.21883 $0.22
5 Schedule 19P Dist.Subtotal $14,559,646 5,083,596 $2.86404 $2.86
Schedule 45 Standby Reservation Charge
6 Total $5.98 $3.12
DERIVATION OF STANDBY DEMAND CHARGES-SCHEDULE 19
Standby Standby
Demand Demand
Unit Cost, Charge Charge
Rev.Reg. Billing Units per kW Primary Transmission
Generation Demand Component
Schedule 19 Production
7 Summer $25,473,464 1,513,792 $16.82759 $16.83 $16.83
8 Non-Summer $42,970,620 2,974,286 $14.44737 $14.45 $14.45
Transmission Demand Component
9 Schedule 19 Transmission $13,607,639 4,488,077 $3.03195 $3.03 $3.03
Distribution Demand Component
10 Schedule 19P Dist.Subtotal $14,559,646 $5,083,596 $2.86404 $2.86
Schedule 45 Total Demand Component
11 Summer $22.72 $19.86
12 Non-Summer $20.34 $17.48
13 Ratio of Sch. 19P/COS;S $13.51 $19.85954 0.68028
14 Ratio of Sch. 19P/COS; NS $12.68 $17.47933 0.72543
15 Ratio of Sch. 19T/COS;S $15.19 $19.85954 0.76487
16 Ratio of Sch. 19T/COS; NS $13.37 $17.47933 0.76490
Schedule 45 Standby Demand Charge
17 Summer $15.46 $15.19
18 Non-Summer $14.76 $13.37
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 39 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Calculation of Proposed Rates
Settlement Stipulation
IPC-E-25-16
Alternative Distribution Service
Schedule 46
DERIVATION OF THE CAPACITY CHARGE
Unit Cost,
per kW
Capacity Charge $2.86
Distribution Line Mileage Charge
Average Construction Mile Cost-
3PH 12.5 kV Crossarm Construction
(Current Design Standard) $78,519.31
Schedule 66 Facilities Charge Maintenance 0.65%
Per kW Per Tenth of a Mile $0.005
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 40 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Schedule 62
Fixed Cost Component of the Retail Energy Charge, per kWh
Time Period Secondary Service Primary Service Transmission Service
Summer On-Peak 1.84370 1.25510 1.27520
Summer Mid-Peak 1.84370 1.25510 1.27520
Summer Off-Peak 1.84370 1.25510 1.27520
Non-Summer On-Peak 1.80010 1.22540 1.2451 ¢
Non-Summer Mid-Peak 1.80010 1.22540 1.24510
Non-Summer Off-Peak 1.8001 ¢ 1.22540 1.24510
Exhibit No.2
Case No. IPC-E-25-16
Settlement Stipulation
Page 41 of 41

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
EXHIBIT NO. 3
NET POWER SUPPLY EXPENSE

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
PCA Components by FERC Account
Settlement Stipulation
IPC-E-25-16
Exhibit No.3-Base Net Power Supply Expense
2025 Base Level NPSE
95%Accounts(with 95%recovery in PCA)
501, Steam $ 108,005,080
536,Water for Power $ -
547,Other Fuel $ 50,540,155
555,Non-PURPA Purchased Power $ 124,823,345
447, Surplus Sales $ (74,447,697)
447-050, Surplus Sales-Transmission $ (10,045,519)
565,Third Party Transmission $ 12,357,059
Net 95%Accounts $ 211,232,422
100%Accounts(with 100%recovery in PCA)
577.4 Energy Storage Rents $ 21,546,000
555,PURPA $ 226,719,444
555,Demand Response $ 9,342,758
Total $ 468,840,624
Exhibit No. 3
Case No.IPC-E-25-16
Settlement Stipulation
Page 1 of 1

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
EXHIBIT NO. 4
FCC AND FCE

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Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
Idaho Power Company
State of Idaho
Derivation of Proposed FCC&FCE Rates
Settlement Stipulation
IPC-E-25-16
Exhibit No.4-FCC and FCE
Existing Customer New Customer
Description January 1,2026 January 1,2026
Average Number of Customers 1,030 1,030
Fixed Cost per Customer $ 908 $ 280
Total Fixed Cost Recovery $ 935,195 $ 288,604
Fixed Cost of Energy $ 0.081838 $ 0.025255
Total kWhs 18,562,155 18,562,155
Fixed Cost Recovery in Energy $ 1,519,090 $ 468,787
Revenue Collection:
Service Charge $ 185,486 $ 185,486
Summer Energy $ 771,333 $ 771,333
Non-Summer Energy 1,283,434 1,283,434
Total Energy $ 2,054,767 $ 2,054,767
....................................................................................................................................................................................................................................................
:Total Revenue $ 2,240,253 $ 2,240,253
:................................................................................................................................................................................................................................................_:
Energy-related Costs in Energy Revenue $ 535,677 $ 1,585,980
..................................................................................................................................................................................................................................................
:Summer Share:
Energy-related Costs in Energy Revenue $ 177,891 $ 526,681
On-Peak Energy 0.069001 0.204290
Mid-Peak Energy 0.034500 0.102145
Off-Peak Energy 0.017250 0.051073
.............._Average................................................................................_$ 0029319 $ 0.086805
............................... :
..................................................... ......................,
....................................................................................................................................................................................................................................................
:Non-Summer Share:
Energy-related Costs in Energy Revenue $ 357,787 $ 1,059,299
On-Peak Energy 0.038567 0.114186
Off-Peak Energy 0.025712 0.076124
................Average................................................................................_$ 0.084780
...............................0:028635 $
..................................................... ......................,
Summer Rates(per kWh)
On-Peak Energy $ 0.299185 $ 0.299185
Mid-Peak Energy 0.149594 0.149594
Off-Peak Energy $ 0.074797 $ 0.074797
Non-Summer Rates(per kWh)
On-Peak Energy $ 0.138347 $ 0.138347
Off-Peak Energy $ 0.092231 $ 0.092231
...................................................................................................................................................................................................................................................
:Implied Summer On-Peak FCE Rate $ 0.230184 $ 0.094895
:Implied Summer Mid-Peak FCE Rate 0.115094 0.047449
:Implied Summer Off-Peak FCE Rate 0.057547 0.023724
:Implied Non-Summer On-Peak FCE Rate 0.099780 0.024161
:Implied Non-Summer Off-Peak FCE Rate $ 0.066519 $ 0.016107
:................................................................................................................................................................................................................................................_:
Exhibit No.4
Case No.IPC-E-25-16
Settlement Stipulation
TOU FCE Derivation Page 6 of 6

Docusign Envelope ID:98A2779B-A262-4A1 F-A686-6936505CD71 D
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
EXHIBIT NO. 5
SALES BASED ADJUSTMENT RATE

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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-16
IDAHO POWER COMPANY
ATTACHMENT NO. 2

Idaho Power Company First Revised Sheet No. ii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. ii
GENERAL RULES AND REGULATIONS INDEX
SHEET
RULE TITLE NUMBER
TitlePage........................................................................................................................... i
IndexPage ................................................................................................................. ii -- iv
RuleA Introduction ................................................................................................................... A-1
RuleB Definitions............................................................................................................ B-1 -- B-2
Rule C Service and Limitations .......................................................................................C-1 -- C-2
RuleD Metering ..............................................................................................................D-1 -- D-2
Rule E Master Metering Standards........................................................................................... E-1
Rule F Service Establishment and Discontinuance .................................................................. F-1
RuleG Billings................................................................................................................ G-1 -- G-2
Rule H New Service Attachments and Distribution Line Installations or Alterations H-1 -- H-14
RuleI Budget Pay Plans................................................................................................... 1-1 -- 1-2
Rule J Continuity, Curtailment and Interruption of Electric Service..................................J-1 —J-4
Rule K Customer's Load and Operations........................................................................ K-1 -- K-2
RuleL Deposits ............................................................................................................... L-1 -- L-2
Rule M Facilities Charge Service.................................................................................... M-1 -- M-3
Rule N Special Arrangements for Substation Allowances and Transmission Vested
Interest .................................................................................................................N-1 --N-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, ID

Idaho Power Company First Revised Sheet No. iii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. iii
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 — 5-3
6 Residential Service On-Site Generation ...............................................................6-1 — 6-9
7 Small General Service ..........................................................................................7-1 — 7-2
8 Small General Service On-Site Generation ..........................................................8-1 — 8-8
9 Large General Service ..........................................................................................9-1 - 9-5
15 Dusk to Dawn Customer Lighting......................................................................15-1 — 15-2
19 Large Power Service.........................................................................................19-1 — 19-4
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 — 33-5
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, ID

Idaho Power Company First Revised Sheet No. iv
cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. iv
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 — 81-4
82 Flex Peak Program (Optional)...........................................................................82-1 — 82-7
84 Customer Energy Production Net Metering Service..........................................84-1 — 84-9
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
97 Kilowatt-Hour Tax.........................................................................................................97-1
98 Residential and Small Farm Energy Credit.......................................................98-1 — 98-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, ID

Idaho Power Company First Revised Sheet No. C-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. C-2
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 and the Company's Customer Requirements for Electric Service (found at
Idahopower.com/requirements).
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. H-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-5
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. Removals in High Fire Risk Zones. The Company reserves the right to remove or de-
energize any electrical equipment without advance written notice if that equipment has not
been used for 1-year.
f. 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.
g. Undeveloped Subdivisions. When electric service is not provided to the individual spaces
or lots within a Subdivision, the Subdivision will be classified as undeveloped.
h. 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.
i. 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. H-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-6
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
2. General Provisions (Continued)
j. 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.
k. 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 31 st 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.
I. 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.
M. Customer Provided Trench Dipping 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. H-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-7
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
4. Service Attachment Charqes
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 $ 28.00
overhead including 2" riser $ 991.00
overhead including 3" riser $1,247.00
Distance charge (per foot)
Company Installed Facilities with:
1/0 underground cable $ 14.97
4/0 underground cable $ 15.98
350 underground cable $ 20.30
Customer Provided Trench & Conduit with:
1/0 underground cable $ 4.11
4/0 underground cable $ 5.12
350 underground cable $ 7.13
ii. Three Phase 400 Amps or Less and Three Phase Self-Contained Multiple Meter
Bases 500 Amps or Less. Only applicable when a single run of service cable is
required.
Underground Service Cable (Base charge plus Distance charge)
Base charge from:
underground $ 80.00
overhead including 2" riser $ 1,072.00
overhead including 3" riser $ 1,352.00
overhead including 4" riser $ 1,644.00
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. H-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-8
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
4. Service Attachment Charges (Continued)
Distance charge (per foot)
Company installed Facilities with:
1/0 underground cable $ 15.77
4/0 underground cable $ 19.13
350 underground cable $ 24.47
Customer Provided Trench & Conduit with:
1/0 underground cable $ 5.01
4/0 underground cable $ 6.27
350 underground cable $ 10.79
iii. The Applicant or Additional Applicant will pay a non-refundable Underground
Service Attachment Charge equal to the Work Order Cost for all requests for
services that are not covered under 4(b)(i) or 4(b)(ii).
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. H-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-9
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
5. Vested Interest Charges (Continued)
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
$97.00 per hour.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. H-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-10
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
6. Other Charges (Continued)
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 - $76.00
The customer-provided meter post must be set within two linear feet of the
Company's existing transformer or junction box.
ii. Overhead - $330.00
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 $76.00 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. H-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. H-11
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
6. Other Charges (Continued)
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.
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$126.00 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 $4,233.00
Non-residence $ 0.00
Non-residential:
Schedules 7, 8, 9, 24
Single Phase $4,233.00
Three Phase $8,707.00
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No H-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-12
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
7. Line Installation, Shared Terminal Facilities and Service Attachment Allowances
(Continued)
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 $4,233.00
Allowance for each single phase transformer installed within a development and a
$8,707.00 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.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. H-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-13
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
8. Refunds (Continued)
ii. A subdivider will be eligible for Vested Interest Refunds for payments for Line
Installations outside subdivisions.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. N - 1
RULE N
SPECIAL ARRANGEMENTS
FOR SUBSTATION ALLOWANCES AND
TRANSMISSION VESTED INTEREST
This rule applies to eligible customers taking service under Schedule 19, or customers taking
Primary or Transmission Service under Schedule 9; when the customer's request for service requires the
installation of new or upgraded transformer capacity in Substation Facilities.
Definitions
Additional Schedule 9 or 19 Applicant is a Schedule 9 or 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 9 or 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 9 or 19 Applicant for new electric
service from the Company.
Connected Load is the total nameplate MW rating of the electric loads connected for Schedule 9
or 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 9 or 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 9 or
19 Applicant holds in a specific section of Transmission Facilities when Additional Schedule 9 or 19
Applicants attach to that section of Transmission Facilities.
Transmission Vested Interest Charge is an amount collected from an Additional Schedule 9 or 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. N - 2
RULE N
SPECIAL ARRANGEMENTS
FOR SUBSTATION ALLOWANCES AND
TRANSMISSION VESTED INTEREST
(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 9 or 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 $99,826 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 9 or 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:
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 9 or 19.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. N - 3
RULE N
SPECIAL ARRANGEMENTS
FOR SUBSTATION ALLOWANCES AND
TRANSMISSION VESTED INTEREST
(Continued)
Transmission Vested Interest (Continued)
Transmission Vested Interest Refunds.
Transmission Vested Interest Refunds will be paid by the Company and funded by the
Additional Schedule 9 or 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 9 or 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 9 or 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 9 or 19 Applicant will pay an amount determined by this equation:
Transmission Vested Interest Charge = A x B where;
A = Load Ratio: Additional Schedule 9 or 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 9 or 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 9 or 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 9 or 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 9 or 19 Applicant.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 1-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 1-2
SCHEDULE1
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 $15.00 $15.00
Energy Charge, per kWh
First 800 kWh 12.11950 9.93320
801-2000 kWh 13.29950 10.43050
All Additional kWh Over 2000 14.61850 11.00520
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 3-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 3-1
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 7'/2 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 $15.00
Energy Charge, per kWh
all kWh 11.94500
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 5-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 5-1
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 7'/2 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 5-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 5-2
SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-USE PLAN
(OPTIONAL)
(Continued)
BILL PROTECTION
Customers who begin service under this schedule on or after January 1, 2026, and who have not
previously received Bill Protection at the Premises, shall be eligible for Bill Protection. Bill Protection
compares the total Energy Charges incurred under this schedule during the initial twelve (12)consecutive
billing months of service to the Energy Charges that would have been incurred under Schedule 1 —
Residential Service (Standard Plan) for the same usage and billing period. If the cumulative Energy
Charges under this schedule exceed those under the Standard Plan by more than ten dollars ($10), the
Customer shall receive a one-time bill credit equal to the net difference reduced by the $10 threshold for
Bill Protection. Customers who do not remain continuously enrolled in this schedule for the full twelve-
month period, who received service under this schedule at the Premises prior to January 1, 2026, or who
have previously received Bill Protection at the Premises, are not eligible. Upon conclusion of the Bill
Protection period, the Customer shall continue service under this schedule unless the Customer notifies
the Company of their intent to return to the Standard Plan or another applicable rate 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 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 5-3
SCHEDULE5
RESIDENTIAL SERVICE
TIME-OF-USE PLAN
(OPTIONAL)
(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 $15.00 $15.00
Energy Charge, per kWh
On-Peak 29.91850 13.83470
Mid-Peak 14.95940 n/a
Off-Peak 7.47970 9.22310
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 6-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-2
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
APPLICABILITY (Continued)
6. Customer meets all applicable requirements detailed in the Company's Schedule 68,
Interconnections to Customer Distributed Energy Resources.
7. Legacy Status for eligible Exporting Systems will terminate December 2045.
8. The Legacy Status of the Exporting System is transferrable to a subsequent Customer at
the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System
taking service under Schedule 6 will be responsible for complying with the terms and conditions of the
on-site generation service in effect for that premises.
9. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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
Legacy System beyond these limits and wishes to maintain Legacy Status for the original system, the
new portion of the DER shall be separately metered and would not qualify for Legacy Status.
11. A Customer with a Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing.
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.
Exported Energy means the kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 6-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-3
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
DEFINITIONS (Continued)
Financial Credit represents the amount in dollars carried forward to offset Customer's Monthly
Charges in a subsequent Billing Period. A Financial Credit is generated during a Billing Period when the
product of Exported Energy and the Export Credit Rate exceeds a Customer Monthly Charges.
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 DER to the Point
of Delivery.
Kilowatt Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly
one-for-one kWh credit compensation for Excess Net Energy.
Legacy System means any system that meets the applicable criteria as described in Order Nos.
34509 and 34546.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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 DERs or its
successor schedule(s) as approved by the Commission.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 6-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-4
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
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.
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering 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. kWh Credits are subject to the following provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh 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 kWh Credits exists at a Designated Meter the Customer may request
to transfer the unused kWh Credits to offset energy consumption at eligible meters. A meter is
eligible for aggregation if it meets all of the following criteria:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 6-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-5
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
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
iv. The electricity recorded by the meter is for the Customer's requirements; and
V. kWh 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 kWh Credits between December 1 and
January 31 of each year. All requests must be received by Idaho Power, on or before January 31.
If a Customer does not request to transfer kWh Credits by the January 31 submission deadline kWh
Credits will carry forward to offset consumption at the Designated Meter until they become eligible
the following year.
C. Requests to transfer kWh Credits must be executed by the Company no later than
March 31. Transfers will be based on the balance of kWh Credits available at the time the transfer
is made.
d. If multiple meters are eligible for aggregation, kWh Credits must first be applied to
the Designated Meter, then to eligible meters on 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.
NET BILLING — CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Billing under this schedule.
1. Balances of usage and exports by the Customer.
a. The Customer shall be billed for the electricity supplied by the Company at the
rates contained within this schedule, in accordance with normal metering practices.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 6-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-6
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
NET BILLING — CONDITIONS OF PURCHASE AND SALE (Continued)
b. The Customer shall be credited for Exported Energy at the applicable Export Credit
Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Financial
Credits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains
electric service at the same Point of Delivery.
ii. Financial Credits are transferrable in the event that a Customer relocates.
If the establishment of service at the new Point of Delivery is not initiated at the time
service at the Designated Meter is discontinued, any unused Financial Credits will be paid
out following the time the final bill is prepared.
2. Aggregation of meters for the annual transfer of unused credits:
a. If a balance of Financial Credits exists at a Designated Meter, the Customer may
request to transfer the unused Financial Credits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer, and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial Credits between December 1 and January 31 of each year. All requests must be
received by Idaho Power, on or before January 31. If a Customer does not request to transfer
Financial Credits by the January 31 submission deadline Financial Credits will carry forward at
the Designated Meter until they become eligible for transfer the following year.
C. Requests to transfer Financial Credits must be executed by the Company no later
than March 31. Transfers will be based on the balance of Financial Credits available at the time
the transfer is made.
A meter aggregation fee of$10.00 will be assessed per aggregated meter per annual transfer transaction.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 6-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 6-9
SCHEDULE6
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 $15.00 $15.00
Energy Charge, per kWh
First 800 kWh 12.11950 9.93320
801-2000 kWh 13.29950 10.43050
All Additional kWh Over 2000 14.61850 11.00520
TIME-OF-USE RATES (OPTIONAL)
Summer Non-summer
Service Charge, per month $15.00 $15.00
Energy Charge, per kWh
On-Peak 29.91850 13.83470
Mid-Peak 14.95940 n/a
Off-Peak 7.47970 9.22310
EXPORT CREDIT RATE
The following rate structure and credits are subject to change upon Commission approval:
Summer Non-summer
Export Credit Rate, per kWh
On-Peak 15.68360 2.90190
Off-Peak 3.39200 2.90190
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 7-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 7-2
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 8.71740 8.71740
All Additional kWh 9.96190 8.71940
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-2
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
APPLICABILITY (Continued)
4. Legacy Status for eligible Exporting Systems will terminate December 2045.
5. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the
premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking
service under Schedule 8 will be responsible for complying with the terms and conditions of the on-site
generation service in effect for that premises.
6. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
7. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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 Legacy
System beyond these limits and wishes to maintain Legacy Status for the original System, the new portion
of the DER shall be separately metered and would not qualify for Legacy Status.
8. A Customer with Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing.
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 Energv 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.
Exported Energy means the kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
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.
Financial Credit represents the amount in dollars carried forward to offset Monthly Charges in a
subsequent Billing Period. A Financial Credit is generated during a Billing Period when the product of
Exported Energy and the Export Credit Rate exceeds a Customer's Monthly Charges.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-3
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
DEFINITIONS (Continued)
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 DER to the Point
of Delivery.
Kilowatt Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly
one-for-one kWh credit compensation for Excess Net Energy.
Legacy System means for any system that meets the applicable criteria as described in Order No.
34509 and 34546.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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 DERs 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-4
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering 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. kWh Credits are subject to the following provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh 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 kWh Credits:
a. If a balance of kWh Credits exists at a Designated Meter, the Customer may request
to transfer the unused kWh 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-5
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
iv. The electricity recorded by the meter is for the Customer's requirements; and
V. kWh 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 kWh Credits between December 1 and
January 31 of each year. All requests must be received by Idaho Power, on or before January 31.
If a Customer does not request to transfer kWh Credits by the January 31 submission deadline kWh
Credits will carry forward to offset consumption at the Designated Meter until they become eligible
for transfer the following year.
C. Requests to transfer kWh Credits must be executed by the Company no later than
March 31. Transfers will be based on the balance of kWh Credits available at the time the transfer
is made.
d. If multiple meters are eligible for aggregation, kWh Credits must first be applied to
the Designated Meter, then to eligible meters on 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.
NET BILLING—CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Billing under the Schedule.
1. Balances of usage and exports by the Customer.
a. The Customer shall be billed for the electricity supplied by the Company at the rates
contained within this schedule, in accordance with normal metering practices.
b. The Customer shall be credited for Exported Energy at the applicable Export Credit
Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Financial
Credits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
ii. Financial Credits are transferrable in the event that a Customer relocates. If the
establishment of service at the new Point of Delivery is not initiated at the time
service at the Designated Meter is discontinued, any unused Financial Credits
will be paid out following the time the final bill is prepared.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6
SCHEDULE8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET BILLING—CONDITIONS OF PURCHASE AND SALE (Continued)
2. Aggregation of meters for the annual transfer of unused Financial Credits:
a. If a balance of Financial Credits exists at a Designated Meter, the Customer may
request to transfer the unused Financial Credits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer, and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial Credits between December 1 and January 31 of each year. All requests must be received
by Idaho Power, on or before January 31. If a Customer does not request to transfer Financial
Credits by the January 31 submission deadline Financial Credits will carry forward at the Designated
Meter until they become eligible for transfer the following year.
C. Requests to transfer Financial Credits must be executed by the Company no later
than March 31. Transfers will be based on the balance of Financial Credits available at the time the
transfer is made.
d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS
1. The Customer shall never deliver or attempt to deliver energy to the Company's system
when the Company's system serving the Customer's DER is de-energized for any reason.
2. 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.
3. The Customer is responsible for all costs associated with the DER 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 DER in order to maintain a safe, reliable electrical system.
4. 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-7
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS (Continued)
5. 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.
6. 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.
7. 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— EXPORT CREDIT RATE
The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain
Time.
Summer Season
On-Peak: 3:00 p.m. to 11:00 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
Off-Peak: All hours Monday through Sunday
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
Sunday, the following Monday will be designated a holiday.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 8-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 8-8
SCHEDULE8
SMALL GENERAL 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 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 8.71740 8.71740
All Additional kWh 9.96190 8.71940
EXPORT CREDIT RATE
The following rate structure and credits are subject to change upon Commission approval:
Summer Non-summer
Export Credit Rate, per kWh
On-Peak 15.68360 2.90190
Off-Peak 3.39200 2.90190
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 9-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No.9-2
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: 11:00 p.m. to 10:00 a.m. and 2:00 p.m. to 7:00 p.m. Monday through
Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 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 10:00 a.m., 2:00 p.m. to 5:00 p.m., and 8:00 p.m. to 6:00 a.m.
Monday through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 p.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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 9-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 9-4
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 $1.84 $1.84
Demand Charge, per kW of Billing Demand
Billing Demand $9.49 $7.75
Energy Charge, per kWh
All kWh 5.09080 4.98750
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 $1.84 $1.84
Demand Charge, per kW of Billing Demand
Billing Demand $9.49 $7.75
Energy Charge, per kWh
On-Peak 6.43290 5.44250
Mid-Peak 4.95420 4.91910
Off-Peak 4.63660 4.63750
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 9-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 9-5
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $345.00 $345.00
Basic Charge, per kW of
Basic Load Capacity $2.04 $2.04
Demand Charge, per kW of
Billing Demand $12.04 $10.48
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.29 n/a
Energy Charge, per kWh
On-Peak 5.36360 4.46790
Mid-Peak 3.98400 3.94750
Off-Peak 3.68750 3.66740
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $345.00 $345.00
Basic Charge, per kW of
Basic Load Capacity $0.67 $0.67
Demand Charge, per kW of
Billing Demand $8.29 $8.69
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.29 n/a
Energy Charge, per kWh
On-Peak 5.61360 4.67030
Mid-Peak 4.21140 4.14650
Off-Peak 3.91010 3.86470
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 15-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 15-2
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 $10.95
85 7,200 $11.67
200 18,000 $14.38
FLOOD LIGHTING
LED Fixture
Watt (Maximum) Lumen (Minimum) Base Rate
85 8,100 $16.14
150 18,000 $17.03
300 32,000 $22.42
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 19-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-2
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: 11:00 p.m. to 10:00 a.m. and 2:00 p.m. to 7:00 p.m. Monday through
Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 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 10:00 a.m., 2:00 p.m. to 5:00 p.m., and 8:00 p.m. to 6:00 a.m.
Monday through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 p.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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 19-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 19-3
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 $110.00 $110.00
Basic Charge, per kW of
Basic Load Capacity $2.27 $2.27
Demand Charge, per kW of
Billing Demand $14.46 $13.05
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.51 n/a
Energy Charge, per kWh
On-Peak 5.95650 4.98790
Mid-Peak 4.50190 4.47230
Off-Peak 4.18940 4.19500
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 19-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 19-4
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $450.00 $450.00
Basic Charge, per kW of $2.32 $2.32
Basic Load Capacity
Demand Charge, per kW of $13.51 $12.68
Billing Demand
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.14 n/a
Energy Charge, per kWh
On-Peak 5.36940 4.41120
Mid-Peak 3.91450 3.89600
Off-Peak 3.60180 3.61870
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $450.00 $450.00
Basic Charge, per kW of
Basic Load Capacity $1.16 $1.16
Demand Charge, per kW of
Billing Demand $15.19 $13.37
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.14 n/a
Energy Charge, per kWh
On-Peak 5.41730 4.43240
Mid-Peak 3.95290 3.91690
Off-Peak 3.63810 3.63950
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 19-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-5
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. 19-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 19-6
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 19-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-7
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 20-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-4
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: 11:00 p.m. to 10:00 a.m. and 2:00 p.m. to 7:00 p.m. Monday through
Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 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 10:00 a.m., 2:00 p.m. to 5:00 p.m., and 8:00 p.m. to 6:00 a.m.
Monday through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 p.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). If New Year's Day, Independence
Day, or Christmas Day falls on Sunday, the following Monday will be considered a holiday.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Sixth Revised Sheet No. 20-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 20-6
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 $345.00 $345.00
Basic Charge, per kW of $2.04 $2.04
Basic Load Capacity
Demand Charge, per kW of $12.68 $11.12
Billing Demand
Energy Charge, per kWh
On-Peak 7.90580 6.61220
Mid-Peak 6.12660 5.37360
Off-Peak 4.54730 4.74820
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $345.00 $345.00
Basic Charge, per kW of
Basic Load Capacity $0.67 $0.67
Demand Charge, per kW of
Billing Demand $8.93 $9.33
Energy Charge, per kWh
On-Peak 8.15580 6.81460
Mid-Peak 6.35400 5.57260
Off-Peak 4.76990 4.94550
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Sixth Revised Sheet No. 20-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 20-7
SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)
MONTHLY CHARGE (Continued)
Large Power Service Rates
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $450.00 $450.00
Basic Charge, per kW of $2.32 $2.32
Basic Load Capacity
Demand Charge, per kW of $14.15 $13.32
Billing Demand
Energy Charge, per kWh
On-Peak 7.86520 6.50910
Mid-Peak 6.01070 5.27570
Off-Peak 4.41520 4.65310
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $450.00 $450.00
Basic Charge, per kW of
Basic Load Capacity $1.16 $1.16
Demand Charge, per kW of
Billing Demand $15.83 $14.01
Energy Charge, per kWh
On-Peak 7.91310 6.53030
Mid-Peak 6.04910 5.29660
Off-Peak 4.45150 4.67390
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 20-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-8
SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)
INTERRUPTION COMPENSATION
Fixed Capacity Reduction Rate:
Larne General Service Rates $0.0453 per kilowatt of reduction per event hour
Larne Power Service Rates $0.0451 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 24-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 24-1
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 not been financially
responsible for an existing Schedule 24 service, 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 begins on June 1 of each year and ends on September
30 of each year.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 24-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 24-3
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 $35.00 $9.00
Demand Charge, per kW of
Billing Demand $16.50 n/a
Energy Charge
All kWh 6.72220 7.07520
TRANSMISSION SERVICE In-Season Out-of-Season
Service Charge, per month $450.00 $9.00
Demand Charge, per kW of
Billing Demand $15.25 n/a
Energy Charge
All kWh 6.30920 6.61360
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 24-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 24-4
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 (1) have
received two or more reminder notices for nonpayment during the most recent 12-month period
during which service was received, when the annual total billed amount on the Schedule 24
account(s) that received the reminder notices is greater than 15 percent of the total annual billed
amount on all Schedule 24 account(s), (2) have had service terminated for nonpayment during
the last four years and have not subsequently received Schedule 24 service, or(3)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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 24-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 24-5
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 when the average of the Cumulative Past Due Balance is equal to or greater than
$750 per service point, or when the Cumulative Past Due Balance is equal to or greater than
$10,000 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 Tier 2 Deposit during any of the
previous four years and who have not subsequently had active Schedule 24 service. The
Company will allow payments for past due balances to be received up to five (5) days after
December 31, without requiring a Tier 2 Deposit. 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fifth Revised Sheet No. 26-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 26-1
SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO
SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED APRIL 11, 2024
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
$3.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$21.04 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
$1.248 per each kW over the Contract Demand.
Monthly Energy Charge
2.71650 per kWh.
Embedded Energy Fixed Cost Charge
0.00000 per kWh of Renewable Resource On-Site Usage
Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos.1, 2, 3, and Second Revised Exhibit 1 of Micron's Special Contract, dated March
9, 2022, as amended.
Renewable Resource Cost
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Excess Generation Credit
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Administrative Charge
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Pricing elements that rely on the most recently filed IRP are effective December 1, 2024,
pursuant to Order No. 36383 issued on November 8, 2024.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 29-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 29-1
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
$3.12 per kW of Contract Demand
Demand Charge,
$17.41 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW
Daily Excess Demand Charge
$1.248 per each kW over the Contract Demand
Energy Charge
2.73770 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 30-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 30-1
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 $14.49
2. Energy Charge, per kWh 3.76990
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 31-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 31-1
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 $3.12
Standby Facilities Contract Demand Charge
Per kW of Standby Facilities Contract Demand:
Paul Facility: $2.72
Nampa Facility: $2.74
Twin Falls Facility: $2.39
Standby Billing Demand Charge, per kW of
Standby Billing Demand $6.93
Excess Demand Charge
$1.248 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 32-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 32-1
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 $3.12 $3.12
Demand Charge
per kW of Billing Demand but no less
than the Contract Demand less 10,000 kW $22.11 $20.17
Daily Excess Demand Charge
per each kW over the Contract Demand $1.248 $1.248
Energy Charge
per kWh 2.75200 2.72020
Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 33-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 33-1
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED MARCH 14, 2024
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: 11:00 p.m. to 10:00 a.m. and 2:00 p.m. to 7:00 p.m. Monday through
Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 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 10:00 a.m., 2:00 p.m. to 5:00 p.m., and 8:00 p.m. to 6:00 a.m.
Monday through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 p.m. Monday through Saturday and all hours on
Sunday and holidays
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 33-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 33-2
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 $450.00 $450.00
Basic Charge, per kW of
Basic Load Capacity $1.16 $1.16
Demand Charge, per kW of
Billing Demand $15.19 $13.37
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.14 n/a
Energy Charge, per kWh
On-Peak 5.41730 4.43240
Mid-Peak 3.95290 3.91690
Off-Peak 3.63810 3.63950
Embedded Energy Fixed Cost Rate, per kWh
On-Peak 1.27520 1.24510
Mid-Peak 1.27520 1.24510
Off-Peak 1.27520 1.24510
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 33-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 33-3
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
$1.248 per each kW over the Contract Demand.
Excess Generation Credit
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021
as amended.
Monthly Contract Demand Charge
$3.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$22.29 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 Second 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 Second Revised Exhibit 3.1 of Brisbie,
LLC's Special Contract, December 22, 2021, as amended.
Supplemental Energy Cost
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021,
as amended.
Administrative Charge
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021,
as amended.
Pricing elements that rely on the most recently filed IRP are effective December 1, 2024, pursuant
to Order No. 36383 issued on November 8, 2024.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 34-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-2
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: 11:00 p.m. to 10:00 a.m. and 2:00 p.m. to 7:00 p.m. Monday
through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 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 10:00 a.m., 2:00 p.m. to 5:00 p.m., and 8:00 p.m. to 6:00 a.m.
Monday through Saturday, except holidays
Off-Peak: 10:00 a.m. to 2:00 p.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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 34-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 34-3
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 $450.00 $450.00
Basic Charge, per kW of
Basic Load Capacity $2.32 $2.32
Demand Charge, per kW of
Billing Demand $13.51 $12.68
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $2.14 n/a
Energy Charge, per kWh
On-Peak 5.18970 4.24380
Mid-Peak 3.73730 3.72850
Off-Peak 3.42530 3.45130
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fifth Revised Sheet No. 34-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 34-4
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
$1.248 per each kW over the Contract Demand.
Monthly Contract Demand Charge
$3.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$24.19 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.
Energy Charge
4.26380 per kWh of Block 2 Energy.
Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 40-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 40-2
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 10.37100
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 $2.50
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 41-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 41-3
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 $15.84
85 7,200 $17.05
140 10,800 $18.54
200 18,000 $21.46
Non-Metered Service —Variable Energy
Energy Charge, per kWh 10.37100
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.
"B" — Customer-Owned, Idaho Power-Maintained System — Discontinued
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 41-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 41-4
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 (41 C)
Energy Charge, per kWh 3.74940
Metered Service (41 CM)
Service Charge, per meter $1.83
Energy Charge, per kWh 3.74940
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 42-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 42-1
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 8.52930
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 45-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 45-3
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 $5.72 $5.72
Primary Service $5.77 $5.77
Transmission Service $3.12 $3.12
Standby Demand Charge, per kW of
Standby Billing Demand
Secondary Service $11.33 $9.44
Primary Service $13.68 $12.55
Transmission Service $8.29 $8.69
Customers taking service under Schedule 19
Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Primary Service $5.98 $5.98
Transmission Service $3.12 $3.12
Standby Demand Charge, per kW of
Standby Billing Demand
Primary Service $15.46 $14.76
Transmission Service $15.19 $13.37
Customers taking service under Schedule 9 or Schedule 19
Excess Demand Charge
$1.248 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 46-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 46-1
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
$2.86 per contracted kW of capacity
Mileage Charge
$0.005 per kW per tenth of a mile in excess of 1.8 miles.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 54-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 54-1
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, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General
Service).
Customers added to Idaho Power's system starting January 1, 2026, 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 $907.64 $280.10
Schedule 5 $907.64 $280.10
Schedule 6 $799.60 $293.77
Small General Service FCC FCC-Dist
Schedule 7 $286.98 $72.64
Schedule 8 $325.39 $107.18
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 54-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 54-2
SCHEDULE 54
FIXED COST ADJUSTMENT
(Continued)
FIXED COST PER ENERGY RATE (Continued)
Residential FCE FCE-Dist
Schedules 1 and 3 8.18380 per kWh 2.52550 per kWh
Schedule 5 — Summer On-Peak 23.01840 per kWh 9.48950 per kWh
Schedule 5 — Mid-Peak 11.50940 per kWh 4.74490 per kWh
Schedule 5 — Summer Off-Peak 5.75470 per kWh 2.37240 per kWh
Schedule 5 — Non-Summer On-Peak 9.97800 per kWh 2.41610 per kWh
Schedule 5 — Non-Summer Off-Peak 6.65190 per kWh 1.61070 per kWh
Schedule 6 9.08360 per kWh 3.33720 per kWh
Small General Service FCE FCE-Dist
Schedule 7 6.12330 per kWh 1.54980 per kWh
Schedule 8 7.33300 per kWh 2.41550 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, 5, and 6) is (0.0503)
cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is
(0.0614) cents per kWh.
EXPIRATION
The Fixed Cost Adjustment included on this schedule will expire May 31, 2026.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 55-2
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) 100 percent of the difference between the Projected Power Costs in Category 4
and the Base Power Costs in Category 4; 5) the Balancing Adjustment; and 6) Earnings Sharing. The
following table calculates the rates for Categories 1, 2, 3, and 4.
The following table shows the determination of PCA rates for Categories 1, 2, 3, and 4:
Base Projected Sharing
Category Description Power Power Difference % Rate
Cost Cost
(¢ per kWh)
The sum of fuel expense and
purchased power expense
(excluding purchases from
1 cogeneration and small power 1.30181 1.89897 0.59716 95% 0.56730
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
Purchased power expense from
2 cogeneration and small power 1.39726 1.39941 0.00215 100% 0.00215
producers.
3 Demand response incentive 0.06008 0.06695 0.00687 100% 0.00687
payments.
4 Payments for battery energy 0.13279 0.11066 (0.02213) 100% (0.02213)
storage system leases
Total 2.89193 3.47599 0.58406 0.55420
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 55-3
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.
Totals may not tie due to rounding.
Balancing Earnings Total PCA
Schedule Category Adjustment Sharing
1 2 3 4
1 0.5673 0.0022 0.0069 0.0221 0.3351 0.0000 0.2191
3 0.5673 0.0022 0.0069 0.0221 0.3351 0.0000 0.2191
5 0.5673 0.0022 0.0069 (0.0221) (0.3351 0.0000 0.2191
6 0.5673 0.0022 0.0069 0.0221 0.3350 0.0000 0.2192
7 0.5673 0.0022 0.0069 0.0221 0.3353 0.0000 0.2189
8 0.5673 0.0022 0.0069 0.0221 0.3355 0.0000 0.2187
9S 0.5673 0.0022 0.0069 0.0221 0.3346 0.0000 0.2196
9P 0.5673 0.0022 0.0069 (0.0221 0.3350 0.0000 0.2192
9T 0.5673 0.0022 0.0069 (0.0221) 0.3349 0.0000 0.2193
15 0.5673 0.0022 0.0069 0.0221 0.3357 0.0000 0.2185
19S 0.5673 0.0022 0.0069 0.0221 0.3350 0.0000 0.2192
19P 0.5673 0.0022 0.0069 0.0221 0.3348 0.0000 0.2194
19T 0.5673 0.0022 0.0069 0.0221 0.3348 0.0000 0.2194
24 0.5673 0.0022 0.0069 0.0221 0.3340 0.0000 0.2202
40 0.5673 0.0022 0.0069 0.0221 0.3349 0.0000 0.2193
41 0.5673 0.0022 0.0069 0.0221 0.3354 0.0000 0.2188
42 0.5673 0.0022 0.0069 0.0221 0.3352 0.0000 0.2190
26 0.5673 0.0022 0.0069 (0.0221) (0.3347) 0.2195
29 0.5673 0.0022 0.0069 (0.0221) (0.3348) 0.2194
30 0.5673 0.0022 0.0069 0.0221 0.3348 0.2194
32 0.5673 0.0022 0.0069 0.0221 0.3348 0.2194
34 0.5673 0.0022 0.0069 0.0221 0.3348 0.2194
* 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
34 Lamb Weston $0.00
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 2026.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective -January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Revised Sheet No. 62-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 62-4
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 Com onent of the Retail E ergy Charge, per kWh
Time Period Secondary Service Primary Service Transmission Service
Summer On-Peak 1.84370 1.2551 ¢ 1.27520
Summer Mid-Peak 1.84370 1.2551 ¢ 1.27520
Summer Off-Peak 1.84370 1.2551 ¢ 1.27520
Non-Summer On-Peak 1.8001 ¢ 1.22540 1.2451 ¢
Non-Summer Mid-Peak 1.8001 ¢ 1.22540 1.2451 ¢
Non-Summer Off-Peak 1.8001 ¢ 1.22540 1.2451 ¢
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 66-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 66-3
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 1.38% 0.64%
Schedule 15 1.74% 1.74%
Schedule 19 1.38% 0.64%
Schedule 24 1.38% 0.64%
Schedule 29 1.38% 0.64%
Schedule 32 1.38% 0.64%
Schedule 41 1.17% 1.17%
Schedule 45 1.38% 0.64%
Schedule 46 1.38% 0.64%
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.
SCHEDULE 68
Monthly Maintenance Charge 0.64%
The monthly Maintenance Charge is determined by multiplying the Monthly Maintenance
Charge by the Company's investment in the System Protection, DER metering, and DER
communication equipment.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-1
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. DERs
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 or prospective 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.
Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator's behalf.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-2
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.
Incomplete Application is an application missing any information needed to satisfy the
requirements of the Customer Interconnection Process; including but not limited to, Customer Generator
signature, the application fee, and details about the Generation Facility.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-4
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,
including the Company's Customer Requirements for Electric Service (found at
idahopower.com/requirements), 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, settings, 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-8
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (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 from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customer Generator
without existing retail service that has not completed the Customer Generator Interconnection Process
requirements by the requested project in-service date identitifed on the completed application will be
considered expired.
Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-9
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)
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 schedule.
2. Customer Generators planning to make system modifications must submit an application,
a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-10
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)
UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)
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
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 DERs with Total Nameplate Capacity less than 3 MVA.
APPLICATION PROCESS
Customer Generators requesting to interconnect a DER less than 3 MVA are required to complete
the following application process prior to interconnection:
1. Customer Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company's website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.
2. Upon receipt of a completed application and a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-11
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)
If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.
If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.
3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
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. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company's evaluation for Upgrades for new customers
conducted in compliance with Rule H — New Service Attachments and Distribution Line Installations or
Alterations.
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.
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 provide the Customer with a Feasiblity Study Agreement which requires a deposit of$1,000
and must be signed and returned within fifteen (15) business days. Upon receipt of the signed Feasibility
Study Agreement and deposit, the Company will perform the Feasiblity Study within thirty (30) 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. At the Company's discretion, additional studies referenced in Section 4 may be
applicable.
a. Installation and funding of the construction, installation, and maintenance
of required Protection Equipment will be subject to the following provisions:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-12
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)
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 specified
in Schedule 66, per month times the investment in the Protection Equipment.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-13
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)
g. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.
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 Customer's
Representative, as identified 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. The rate change will be no later
than the Customer's next Billing Period following their successfully completed inspection. Upon
completion of this process, the Customer will receive confirmation that the application process has been
successfully completed.
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.
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS
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.The capacity of an Energy Storage Device shall
not be used to calculate the 25 kVA capacity limit but will be used to calculate Total Nameplate Capacity
for the Feasbility Review.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-14
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)
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.
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:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-15
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)
UNAUTHORIZED INADVERTENT EXPORT (Continued)
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 (off)
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.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-18
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)
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 as specified in Schedule 66 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
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-2
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
APPLICABILITY (Continued)
ii. Single-Meter Interconnection (applicable to new applicants effective
December 2, 2020): Owns and/or operates a Generation Facility 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 a single meter.
6. The Generation Facility must have a total nameplate rating equal to or less than the
greater of: (a) the greatest monthly Billing Demand established during the most recent 12-month period
at the time of applying for interconnection, which includes and ends with the most recent Billing Period,
or (b) 100 kW. The capacity of an Energy Storage Device shall not be used to calculate the capacity
limits in this schedule.
a. Subject to the Company's discretion and approval, for a Customer applying to
interconnect a Generation Facility (1) where 12-months of Billing Demand is not available, or (2)
where the Billing Demand is not reflective of future operations, the customer may provide
evidence that the proposed Generation Facility meets the applicability of this schedule in
accordance with one of the following:
i. Schedules 9 and 19:
a. If previous billing data is available for the premises and the Customer's
electrical needs are similar to the previous customer, the Company may rely on available
historical Billing Demand at the premises not to exceed the previous 12 months.
b. If the Customer has another account in the Company's service area with
similar electrical needs, the Company may rely on available historical Billing Demand
from that account not to exceed the previous 12 months.
c. The Customer can have a third-party currently licensed or registered
professional engineer provide analysis and documentation detailing the electrical load
requirements for the Customer which support the requested load or an increase in
demand expected to occur.
ii. Schedule 24:
a. If historical Billing Demand is available for the Premises and is still
reflective of expected operations, the Company will rely on the maximum of the most
recently available 12-months of Billing Demand.
b. For newly installed equipment, the Customer may submit documentation
of the horsepower ("HP") of the irrigation equipment (motors and/or pumps). Based on
the submitted documentation, the Company will determine the maximum continuous HP
using a conversion factor of 1 HP to 0.8 kW to define the demand for the Point of
Delivery.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-3
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
APPLICABILITY (Continued)
7. Legacy Status for eligible Exporting Systems will terminate on December 1, 2045.
8. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the
premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System
taking service under Schedule 84 will be responsible for complying with the terms and conditions of the
on-site generation service in effect for that premises.
9. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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
Legacy System beyond these limits and wishes to maintain Legacy Status for the original system, the
new portion of the DER shall be separately metered and would not qualify for Legacy Status.
11. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the
Legacy Status of the Generation Facility.
12. A Customer with a Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing. A Customer forfeiting Legacy Status will be required
to reconfigure to a single-meter system.
DEFINITIONS
Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum
use during the Billing Period, adjusted for Power Factor.
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.
Exported Energy means all kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-4
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
DEFINITIONS (Continued)
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.
Financial Credit represents the amount in dollars carried forward to offset Monthly Charges in a
subsequent Billing Period. A Financial Credit is generated during a Billing Period when the product of
Exported Energy and the Export Credit Rate exceeds a Customer's Monthly Charges.
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.
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 DER to the
Point of Delivery or Generation Interconnection Point.
Kilowatt-Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net
monthly one-for-one kWh credit compensation for Excess Net Energy.
Legacy Systems means any system that meets the applicable criteria as described in Order Nos.
34509, 34546, 34854 and 34892.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-5
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
DEFINITIONS (Continued)
Schedule 68 is the Company's service schedule which provides for interconnection to DERs or its
successor schedule(s) as approved by the Commission.
MONTHLY BILLING
The Customer shall be billed in accordance with the Customer's applicable standard service
schedule, including appropriate monthly charges, and the Export Credit Rate under this schedule.
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering 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. 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. kWh Credits are subject to the following provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh Credits will expire at the time the final bill is prepared.
2. Aggregation of meters for the annual transfer of unused kWh Credits:
a. If a balance of kWh Credits exists at a Designated Meter, the Customer may
request to transfer the unused kWh Credits to offset energy consumption at eligible meters. A
meter is eligible for aggregation if it meets all of the following criteria:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-6
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
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
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, kWh
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, kWh
Credits may only be transferred to meters taking service under Schedule 9, Schedule 19,
or Schedule 24.
b. Customers may submit requests to transfer kWh Credits between December 1 and
January 31 of each year. All requests must be received by Idaho Power, on or before January 31.
If a Customer does not request to transfer kWh Credits by the January 31 submission deadline
kWh Credits will carry forward to offset consumption at the Designated Meter until they become
eligible the following year.
C. Requests to transfer kWh Credits must be executed by the Company no later than
March 31. Transfers will be based on the balance of kWh Credits available at the time the
transfer is made.
d. If multiple meters are eligible for aggregation, kWh Credits must first be applied to
the Designated Meter, then to eligible meters on 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.
NET BILLING—CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to transactions for Net Billing under this schedule.
1. Balances of usage and exports by the Customer.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-7
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET BILLING—CONDITIONS OF PURCHASE AND SALE (Continued)
a. The Customer shall be billed for the electricity supplied by the Company at the
rates contained within the Customer's applicable standard service schedule, in accordance with
normal metering practices.
b. The Customer shall be credited for Exported Energy at the applicable Export
Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges.
Financial Credits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains
electric service at the same Point of Delivery.
ii. Financial Credits are transferrable in the event that a Customer relocates.
If the establishment of service at the new Point of Delivery is not initiated at the time
service at the Designated Meter is discontinued, any unused Financial Credits will be
paid out following the time the final bill is prepared.
2. Aggregation of meters for the annual transfer of unused Financial Credits:
a. If a balance of Financial Credits exists at a Designated Meter, the Customer may
request to transfer the unused Financial Credits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer; and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial Credits between December 1 and January 31 of each year. All requests must be
received by Idaho Power on or before January 31. If a Customer does not request to transfer
Financial Credits by the January 31 submission deadline Financial Credits will carry forward at
the Designated Meter until they become eligible for transfer the following year.
C. Requests to transfer Financial Credits must be executed by the Company no
later than March 31. Transfers will be based on the balance of Financial Credits available at the
time the transfer is made.
d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.
NET ENERGY METERING & NET BILLING— GENERAL CONDITIONS
1. The Customer shall never deliver or attempt to deliver energy to the Company's system when
the Company's system serving the Customer's DER is de-energized for any reason.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 84-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-8
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS (Continued)
2. 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.
3. The Customer is responsible for all costs associated with the DER 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 DER in order to maintain a safe, reliable electrical system.
4. 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.
5. 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.
6. 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.
7. 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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r -a-First Revised Sheet No. ii
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fourth Reyms `Original Sheet No. ii
GENERAL RULES AND REGULATIONS INDEX
SHEET
RULE TITLE NUMBER
TitlePage........................................................................................................................... i
IndexPage ................................................................................................................. ii -- iv
RuleA Introduction ................................................................................................................... A-1
RuleB Definitions............................................................................................................ B-1 -- B-2
Rule C Service and Limitations .......................................................................................C-1 -- C-2
RuleD Metering ..............................................................................................................D-1 -- D-2
Rule E Master Metering Standards........................................................................................... E-1
Rule F Service Establishment and Discontinuance .................................................................. F-1
RuleG Billings................................................................................................................ G-1 -- G-2
Rule H New Service Attachments and Distribution Line Installations or Alterations H-1 -- H-14
RuleI Budget Pay Plans................................................................................................... 1-1 -- 1-2
Rule J Continuity, Curtailment and Interruption of Electric Service..................................J-1 —J-4
Rule K Customer's Load and Operations........................................................................ K-1 -- K-2
RuleL Deposits ............................................................................................................... L-1 -- L-2
Rule M Facilities Charge Service.................................................................................... M-1 -- M-3
Rule N Special Arrangements for Substation Allowances and Transmission Vested
Interest .................................................................................................................N-1 --N-3
IDAHO Issued by IDAHO POWER COMPANY
Issued peer Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 20246 1221 West Idaho Street, Boise, ID

Idaho Power Company QFig+aa-First Revised Sheet No. iii
Cancels
I.P.U.C. No. 30, Tariff No. 101Seventh Revs a Original Sheet No. iii
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 — 5-23
6 Residential Service On-Site Generation .............................................................6-1 — 6-69
7 Small General Service ..........................................................................................7-1 — 7-2
8 Small General Service On-Site Generation ........................................................8-1 — 8-58
9 Large General Service ..........................................................................................9-1 — 9-5
15 Dusk to Dawn Customer Lighting......................................................................15-1 — 15-2
19 Large Power Service.......................................................................................19-1 — 19-74
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 — 33-45
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—_January 1, 20246 1221 West Idaho Street, Boise, ID

Idaho Power Company Qr First Revised Sheet No. iv
cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. iv
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 — 81-34
82 Flex Peak Program (Optional)...........................................................................82-1 — 82-7
84 Customer Energy Production Net Metering Service........................................84-1 — 84-69
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
97 Kilowatt-Hour Tax.........................................................................................................97-1
98 Residential and Small Farm Energy Credit.......................................................98-1 — 98-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—January 1, 20246 1221 West Idaho Street, Boise, ID

Idaho Power Company 9r+g+naI_First Revised Sheet No. C-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Reyosed0riginal Sheet No. C-2
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 and the Company's Customer Requirements for Electric Service (found at
Idahopower.com/requirements).
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—_ january , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original-First Revised Sheet No. H-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst ReyosecOriginal Sheet No. H-5
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. Removals in High Fire Risk Zones. The Company reserves the right to remove or de-
energize any electrical equipment without advance written notice if that equipment has not
been used for 1-year.
ef. 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.
fg. Undeveloped Subdivisions. When electric service is not provided to the individual spaces
or lots within a Subdivision, the Subdivision will be classified as undeveloped.
gh. 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.
hi. 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— jaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r+giRal-First Revised Sheet No. H-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst RevoseeOriginal Sheet No. H-5
All loct
3s mutually agreed othei.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary„ , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original-First Revised Sheet No. H-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst ReyosecOriginal Sheet No. H-6
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
2. General Provisions (Continued)
j. --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.
}k. 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 31 st 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.
ki. 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.
Im. Customer Provided Trench Dipping 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGGRdThird Revised Sheet No. H-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 €#st-Second Revised Sheet No. H-7
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 $ 28.00
overhead including 2" riser $ 991.00
overhead including 3" riser $1,247.00
Distance charge (per foot)
Company Installed Facilities with:
1/0 underground cable $ 14.97
4/0 underground cable $ 15.98
350 underground cable $ 20.30
Customer Provided Trench & Conduit with:
1/0 underground cable $ 4.11
4/0 underground cable $ 5.12
350 underground cable $ 7.13
ii. Three Phase 400 Amps or Less and Three Phase Self-Contained Multiple Meter
Bases 500 Amps or Less. Only applicable when a single run of service cable is
required.
Underground Service Cable (Base charge plus Distance charge)
Base charge from:
underground $ 80.00
overhead including 2" riser $ 1,072.00
overhead including 3" riser $ 1,352.00
overhead including 4" riser $ 1,644.00
IDAHO Issued by IDAHO POWER COMPANY
Issued — noGomhor 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-- n aFGh 15, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho
nd„Ir.o Ne 2-4_95

Idaho Power Company SeGGRd Third Revised Sheet No. H-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 €4rst-Second Revised Sheet No. H-7
ps, and
if a three phase, single phase greaterth-an 400 afflp' er_111'._ r-hA-F;R F;Rlf AA,
Multiple Age.er @so greater 5-00 amp underground Service . M
required, the Applioant ex Appileant will pay a Ron
IDAHO Issued by IDAHO POWER COMPANY
Issued — DeGer ber 20 2024per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—-
n aFGh 15, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho
nd„ipo nip 24_05

Idaho Power Company Seed Third Revised Sheet No. H-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 irst-Second Revised Sheet No. H-8
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
4. Service Attachment Charges (Continued)
Distance charge (per foot)
Company installed Facilities with:
1/0 underground cable $ 15.77
4/0 underground cable $ 19.13
350 underground cable $ 24.47
Customer Provided Trench & Conduit with:
1/0 underground cable $ 5.01
4/0 underground cable $ 6.27
350 underground cable $ 10.79
iii. All Three Phase. Smnqje Phase Greater than 400 AmDs. and Sonale Phase Self
Contained M ltiole Meter BasesRases Greater Tthan 500
f a throe phase oinale nhoco areater than non amp or cinnlo nhoco self_nontainelJ
multoole meter base r-ater than ..nn -Arno un`J ro ind CeRTre Attachment is
req ir- d The Applicant or Additional Applicant will pay a non-refundable
Underground Service Attachment Charge equal to the Work Order Cost for all
requests for services that are not covered under 4(b)(i) or 4(b)(ii)_
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued- DeGemher 20 202- per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- Mar„h 15, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
dVir e Ne 24 05

Idaho Power Company SeGGRd Third Revised Sheet No. H-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 €#st-Second Revised Sheet No. H-8
farac
A Q req re to prepay all
RA ill be calculated
IDAHO Issued by IDAHO POWER COMPANY
Issued_ DeGe nber 20 202- per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— MaFGh 15, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company Seed Third Revised Sheet No. H-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 irst-Second Revised Sheet No. H-9
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
5. Vested Interest Charges (Continued)
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
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
$97.00 per hour.
6. Other Charges /I ontir�ued
v
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued — DeGernber 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Mar„h 15, 202-5january 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company SeGGRdThird Revised Sheet No. H-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 irst-Second Revised Sheet No. H-9
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.
and- refflava 6-0-sts of pro, rary Lone
9-t09 er Pro ,idea ..+., PER miir+ .,0ar f.,.,+ --. +h.,
IDAHO Issued by IDAHO POWER COMPANY
Issued — DeGernber 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— MaFGh 15, 202-5january 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company SeGGndThird Revised Sheet No. H-10
Cancels
I.P.U.C. No. 30, Tariff No. 101€4rst-Second Revised Sheet No. H-10
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
6. Other Charges (Continued)
f. Temporary Line Installation Charge. Applicants or Additional Applicants will pay the
installation and removal costs of providing Temporary Line Installations.
9. Temporary Service Attachment Charge. Applicants or Additional Applicants will pay for
Temporary Service Attachments as follows:
i. Underground - $76.00
The customer-provided meter post must be set within two linear feet of the
Company's existing transformer or function box.
ii. Overhead - $330.00
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 $76.00 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued - DeGer ber 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Mar„h 15, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company SeGGRd Third Revised Sheet No. H-10
Cancels
I.P.U.C. No. 30, Tariff No. 101€4rst-Second Revised Sheet No. H-10
d-.m to Upon completion of that pokien of the mrn'onpf which in-1 1 enditions estio I-
IDAHO Issued by IDAHO POWER COMPANY
Issued - DeGe nber 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— MaFGh 15, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company SeGGndThird Revised Sheet No. H-11
Cancels
I.P.U.C. No. 30, Tariff No. 101€4rst-Second Revised Sheet No. H-11
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
6. Other Charges (Continued)
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.
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$126.00 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 $4,233.00
Non-residence $ 0.00
Non-residential:
Schedules 7, 8, 9, 24
Single Phase $4,233.00
IDAHO Issued by IDAHO POWER COMPANY
Issued — DeGernber 20 2024 per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— MaFGh 15, 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_nti

Idaho Power Company SeGGRd Third Revised Sheet No. H-11
Cancels
I.P.U.C. No. 30, Tariff No. 101€4rst-Second Revised Sheet No. H-11
Three Phase $8,707.00
IDAHO Issued by IDAHO POWER COMPANY
Issued — DeGernber 20 2024per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Mar„h 15, 202-5january 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe nip 24_nti

Idaho Power Company Original FirstRevised Sheet No H-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-12
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
7. Line Installation, Shared Terminal Facilities and Service Attachment Allowances
(Continued)
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 $4,233.00
Allowance for each sjngle phase transformer installed within a development and a
8,707.00 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.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised 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. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rig.—First Revised Sheet No. H-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. H-13
RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)
8. Refunds (Continued)
ii. H. A subdivider will be eliaible for Vested Interest Refunds for payments for
Line Installations outside subdivisions.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 1-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Seed-Third Revised Sheet No. 1-2
SCHEDULE1
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 $15.00 $15.00
Energy Charge, per kWh
First 800 kWh 10.177912.11950 8.95699.93320
801-2000 kWh 12.238013.29950 9.875010.43050
All Additional kWh Over 2000 14.538514.6185¢ 111.00520
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 3-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 3-1
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 7'/2 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 $15.00
Energy Charge, per kWh
all kWh 10.948211.94500
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal-First Revised Sheet No. 5-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fe art" Rev'sed0riginal Sheet No. 5-1
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 7'/2 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.
ci innnn�Q nnin ninni ci innnn�� c�nennic
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2G24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 5-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Segend-Third Revised Sheet No. 5-2
SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-USE PLAN
(OPTIONAL)
(Continued)
BILL PROTECTION
Customers who begin service under this schedule on or after January 1, 2026, and who have
not previously received Bill Protection at the Premises, shall be eligible for Bill Protection. Bill Protection
compares the total Energy Charges incurred under this schedule during the initial twelve (12)
consecutive billing months of service to the Energy Charges that would have been incurred under
Schedule 1 — Residential Service (Standard Plan) for the same usage and billing period. If the
cumulative Energy Charges under this schedule exceed those under the Standard Plan by more than
ten dollars ($10), the Customer shall receive a one-time bill credit equal to the net difference reduced
by the $10 threshold for Bill Protection. Customers who do not remain continuously enrolled in this
schedule for the full twelve-month period, who received service under this schedule at the Premises
prior to January 1, 2026, or who have previously received Bill Protection at the Premises, are not
eligible. Upon conclusion of the Bill Protection period, the Customer shall continue service under this
schedule unless the Customer notifies the Company of their intent to return to the Standard Plan or
another applicable rate 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 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.
nnnniTui v �unpcP
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 5-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 5-2
RMAII Farm
nergy -Fee
1-0 W
ten,,.-,.., rh.,,- ,,
aI,-
Peak 2529570
Off o k 624
AYME=NT
nr
past due 15 days from the date- an vihidh
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 5-3
SCHEDULE5
RESIDENTIAL SERVICE
TIME-OF-USE PLAN
(OPTIONAL)
(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 Feesl 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 $15.00 $15.00
Energy Charge, per kWh
On-Peak 25.295729.91850 913.8347r�
Mid-Peak 42.648814.95940 n/a
Off-Peak 6.32417.47970 8.74339.2231�0
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 Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral-First Revised Sheet No. 6-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst RevisecOriginal Sheet No. 6-2
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
APPLICABILITY (Continued)
6. Customer meets all applicable requirements detailed in the Company's Schedule 68,
Interconnections to Customer Distributed Energy Resources.
7. Legacy Status for eligible Exporting Systems will terminate December 2045.
8. The Legacy Status of the Exporting System is transferrable to a subsequent Customer at
the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System
taking service under Schedule 6 will be responsible for complying with the terms and conditions of the
on-site generation service in effect for that premises.
9. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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
Legacy System beyond these limits and wishes to maintain Legacy Status for the original system, the
new portion of the DER shall be separately metered and would not qualify for Legacy Status.
11. A Customer with a Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing.
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.
Exported Energy means the kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— jaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 6-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro Rey'seelOriginal Sheet No. 6-2
-nma--Marl hit
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 6-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sed0riginal Sheet No. 6-3
SCHEDULE6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
DEFINITIONS (Continued)
Financial Credit represents the amount in dollars carried forward to offset Customer's Monthly
Charges in a subsequent Billing Period. A Financial Credit is generated during a Billing Period when the
product of Exported Energy and the Export Credit Rate exceeds a Customer Monthly Charges.
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 DER to the Point
of Delivery.
Kilowatt Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly
one-for-one kWh credit compensation for Excess Net Energy.
Legacy System means any system that meets the applicable criteria as described in Order Nos.
34509 and 34546.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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 DERs or its
successor schedule(s) as approved by the Commission.
TVDC rlC CCD\/I(`C
. ..e- type ef serviee p­iddedd un-e., this se-hed-le is single phase riternating eurrent a
0
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRuary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral-First Revised Sheet No. 6-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Corot Rey'seelOriginal Sheet No. 6-3
family dwellings, the Gempany may provide AWIto
p.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal-First Revised Sheet No. 6-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sed0riginal Sheet No. 6-4
SCHEDULE6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
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.
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering 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 eCredit to offset energy usage in a subsequent Billing
Period. kWh CreditsEXGess Net EReFgy eredifs-are subject to the following provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh GCredits 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 E^erg kWh eCredits exists at a Designated Meter the
Customer may request to transfer the unused kWh eCredits to offset energy consumption at eligible
meters. A meter is eligible for aggregation if it meets all of the following criteria:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jarlyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral-First Revised Sheet No. 6-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst RevisecOriginal Sheet No. 6-5
SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
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
iv. The electricity recorded by the meter is for the Customer's requirements; and
V. kWh 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 EXGess Net EnergykWh -GCredits
between December 1 and January 31 of each year. All requests must be received by Idaho Power
by midnight MO intro StaR daFd Tome, on or before January 31. If a Customer does not request to
transfer EXGess Net Ene gykWh -CCredits by the January 31 submission deadline EXGess
EnRergykWh eCredits will carry forward to offset consumption at the Designated Meter until they
become eligible the following year.
C. Requests to transfer EXGess Net EReFg / kWh eCredits must be executed by the
Company no later than March 31. Transfers will be based on the balance of EXGess Net ET or kWh
sCredits available at the time the transfer is made.
d. If multiple meters are eligible for aggregation, EXGess Net E 4er-g 'kWh eCredits must
first be applied to the Designated Meter, then to eligible meters on 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.
NET BILLING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Billing under this schedule.
1. Balances of usage and exports by the Customer.
a. The Customer shall be billed for the electricity supplied by the Company at the
rates contained within this schedule, in accordance with normal metering practices.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- Jane��, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal-First Revised Sheet No. 6-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Revosed0riginal Sheet No. 6-6
SCHEDULE6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)
NET BILLING — CONDITIONS OF PURCHASE AND SALE (Continued)
b. The Customer shall be credited for Exported Energy at the applicable Export Credit
Rate contained within this schedule as a credit in dollars to only offset Monthly Charges.. Elea
Eby. -Financial gCredits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains
electric service at the same Point of Delivery.
ii. Financial Credits are transferrable in the event that a Customer relocates.
If the establishment of service at the new Point of Delivery is not initiated at the time
service at the Designated Meter is discontinued, �:�the C Customer's respeRSihility to
_ed at theneW IGGat'en in Idaho Pow
request the Gredit transfer when SeFV'Ge is
seFViGe eaany unused Financial Credits will be paid out following the time the final bill is
prepared.
If a Customer stomer dicnontini es SeNiGes at the Point of Delivery acconiated with
the Experting System and dees net intend to establish seFViGe at anether loGatien On Id
Pewer's serViGe area aRy URysed Gredits will be paid GUt f0lleWiRg the time the fiRal
2. Aggregation of meters for the annual transfer of unused credits:
a. If a balance of Financial ECredits exists at a Designated Meter, the Customer may
request to transfer the unused Financial eCredits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer, and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial eCredits between December 1 and January 31 of each year. All requests must be
received by Idaho Power by midnight Mountain Standard Timo on or before January 31. If a
Customer does not request to transfer Financial eCredits by the January 31 submission deadline
Financial eCredits will carry forward at the Designated Meter until they become eligible for transfer
the following year.
G. Requests to transfer Financial eCredits must be executed by the Company no later
than
C. March 31. Transfers will be based on the balance of Financial eCredits available
at the time the transfer is made.
d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer
transaction.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 6-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 6-9
SCHEDULE6
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 $15.00 $15.00
Energy Charge, per kWh
First 800 kWh 10.177912.11950 8.95699.93320
801-2000 kWh 12.238013.29950 9.875010.4305¢
All Additional kWh Over 2000 14.538514.61850 4$936111.00520
TIME-OF-USE RATES (OPTIONAL)
Summer Non-summer
Service Charge, per month $15.00 $15.00
Energy Charge, per kWh
On-Peak 25.295729.91850 1 2�13.83470
Mid-Peak 12.648014.95940 n/a
Off-Peak 6.32417.47970 _ 4w9.2231¢
EXPORT CREDIT RATE
The following rate structure and credits are subject to change upon Commission approval:
Summer Non-summer
Export Credit Rate, per kWh
On-Peak 15.68360 2.90190
Off-Peak 3.39200 2.90190
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 Issued by IDAHO POWER COMPANY
Issued per Order Nos. 36775 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 7-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Segend-Third Revised Sheet No. 7-2
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 7.45348.71740 7.45348.71740
All Additional kWh 8.51769.96190
', 4-8.71940
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal-First Revised Sheet No. 8-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sed0riginal Sheet No. 8-2
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
APPLICABILITY (Continued)
4. Legacy Status for eligible Exporting Systems will terminate December 2045.
5. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the
premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking
service under Schedule 8 will be responsible for complying with the terms and conditions of the on-site
generation service in effect for that premises.
6. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
7. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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 Legacy
System beyond these limits and wishes to maintain Legacy Status for the original System, the new portion
of the DER shall be separately metered and would not qualify for Legacy Status.
8. A Customer with Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing_
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 Energv 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.
Exported Energy means the kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
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.
Financial Credit represents the amount in dollars carried forward to offset Monthly Charges in a
subsequent Billing Period. A Financial Credit is generated during a Billing Period when the product of
Exported Energy and the Export Credit Rate exceeds a Customer's Monthly Charges.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRuary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Corot Rey'seelOriginal Sheet No. 8-2
0-read to the -offir
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sed0riginal Sheet No. 8-3
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
DEFINITIONS (Continued)
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 DER to the Point
of Delivery.
Kilowatt Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly
one-for-one kWh credit compensation for Excess Net Energy.
Legacy System means for any system that meets the applicable criteria as described in Order No.
34509 and 34546.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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 DERs 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.
��v�nnn���r�nniniTinnic n� �i i�rune� nni
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Corot Rey'seelOriginal Sheet No. 8-3
the -ompapy during
ty
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-jaRyary„ , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sed0riginal Sheet No. 8-4
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering 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.
ET ENEQ�METERING CONDITIONS OF PURCHASE AND SALE (Gentiniiorll
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 GCredit to offset energy usage in a subsequent Billing
Period. EXGess Net E^erry kWh GCredits are subject to the following provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh c-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 EXGess Net E eefgy Wh GCredits:
a. If a balance of EXGess Net Grler kWh GCredits exists at a Designated Meter, the
Customer may request to transfer the unused kWh GCredits 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jarlyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro Rey'seelOriginal Sheet No. 8-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9FigiRaLFirst Revised Sheet No. 8-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth ReyosecOriginal Sheet No. 8-5
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
iv. The electricity recorded by the meter is for the Customer's requirements: and
V. kWh 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 EXGess Net ERern"kWh eCredits
between December 1 and January 31 of each year. All requests must be received by Idaho Power
Time,by midnight, Mountain Standard on or before January 31. If a Customer does not request to
transfer EXGess Net EnergykWh eCredits by the January 31 submission deadline EXGess
EnRergykWh GCredits will Gcarry forward to offset consumption at the Designated Meter until they
become eligible for transfer the following year.
C. Requests to transfer EXGess Net CnorgykWh eCredits must be executed by the
Company no later than March 31. Transfers will be based on the balance of EXGess Net&orn„kWh
GCredits available at the time the transfer is made.
d. If multiple meters are eligible for aggregation, EXGess Net Energy Wh eCredits must
first be applied to the Designated Meter, then to eligible meters on 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.
NET BILLING—CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Billing under the Schedule.
1. Balances of usage and exports by the Customer.
a. The Customer shall be billed for the electricity supplied by the Company at the rates
contained within this schedule, in accordance with normal metering practices.
b. The Customer shall be credited for Exported Energy at the applicable Export Credit
Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. €xperted
En�Financial GCredits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
i�Financial Credits are transferrable in the event that a Customer relocates. If the
establishment of service at the new Point of Delivery is not initiated at the time
service at the Designated Meter is discontinued, any unused Financial Credits
will be paid out following the time the final bill is prepared.it is the Customer's
resperlSibility te request the Gredit transfer when seFViGe is established at the
new IGGatien in Idaho Power's corvine area
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Jane�, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal-First Revised Sheet No. 8-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sixth Reyose'[Original Sheet No. 8-5
ii.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6
SCHEDULE8
SMALL GENERAL SERVICE
ON-SITE GENERATION
(Continued)
NET BILLING—CONDITIONS OF PURCHASE AND SALE (Continued)
Idaho Power's seNoGe area any unus d Gredits will be oawd out fallowona the a rne
the final hill is rror»rorl
2. Aggregation of meters for the annual transfer of unused Financial eCredits:
a. If a balance of Financial eCredits exists at a Designated Meter, the Customer may
request to transfer the unused Financial eCredits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer, and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial eCredits between December 1 and January 31 of each year. All requests must be
received by Idaho Power by ^fin}, MGURtain Standard Tie, on or before January 31. If a
Customer does not request to transfer Financial eCredits by the January 31 submission deadline
Financial eCredits will carry forward at the Designated Meter until they become eligible for transfer
the following year.
c. Requests to transfer Financial eCredits must be executed by the Company no later
than March 31. Transfers will be based on the balance of Financial eCredits available at the time
the transfer is made.
d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS
1. The Customer shall never deliver or attempt to deliver energy to the Company's system
when the Company's system serving the Customer's DER is de-energized for any reason.
2. 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.
3. The Customer is responsible for all costs associated with the DER 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 DER in order to maintain a safe, reliable electrical system.
4. 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
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-7
SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERATION
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS (Continued)
5. 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.
6. 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.
7. 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— EXPORT CREDIT RATE
The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain
Time.
Summer Season
On-Peak: 3:00 p.m. to 11:00 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
Off-Peak: All hours Monday through Sunday
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
Sunday, the following Monday will be designated a holiday.
nnnniTui v run���
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRyary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 8-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— jaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 8-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Sid-Third Revised Sheet No. 8-8
SCHEDULE8
SMALL GENERAL 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).
MONTHLY CHARGE
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 7.45348.71740 7 45348.71740
All Additional kWh 8.51769.96190 7.45528.71940
EXPORT CREDIT RATE
The following rate structure and credits are subject to change upon Commission approval:
Summer Non-summer
Export Credit Rate, per kWh
On-Peak 15.68360 2.90190
Off-Peak 3.39200 2.90190
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 Issued by IDAHO POWER COMPANY
Issued per Order Nos. 36775 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — OGteber1,202-5January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal-First Revised Sheet No. 9-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Rowse dOriginal Sheet No.9-2
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: 611:00 p.m. to 710:00 pa.m. and 442:00 p.m. to 4-27:00 ap.m. Monday
through Saturday, except holidays
Off-Peak: 4-210:00 a.m. to 32:00 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 120:00 pa.m., 42:00 p.m. to 5:00 p.m., and 8:00 p.m. to 4-06:00
pa.m. Monday through Saturday, except holidays
Off-Peak: :00 a.Rq. + 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 pa.m. to 4-2:00
ap.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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 9-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 9-4
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 $4591.84
$4381.84
Demand Charge, per kW of Billing Demand
Billing Demand $8—.1-29.49
$6—.397.75
Energy Charge, per kWh
All kWh 5.46585.09080
5.27214.98750
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 $4381.84
$4-.-591.84
Demand Charge, per kW of Billing Demand
Billing Demand $8-429.49
$&.397.75
Energy Charge, per kWh
On-Peak 5-84896.43290
5.57555.44250
Mid-Peak 5.84894.95420
5.32594.9191¢
Off-Peak 5.27094.63660
5:42734.63750
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 9-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 9-5
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $340.00345.00
$340.00345.00
Basic Charge, per kW of
Basic Load Capacity $4-832.04 $4-832.04
Demand Charge, per kW of
Billing Demand $8-.3512.04 $7-.9410.48
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4 592.29 n/a
Energy Charge, per kWh
On-Peak 5.39375.36360
4.89954.46790
Mid-Peak 5.39373.98400
4.65793.94750
Off-Peak 4.83463.68750
4.46493.66740
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $340.00345.00
$340.00345.00
Basic Charge, per kW of
Basic Load Capacity $4-09.067 $4-. 9.067
Demand Charge, per kW of
Billing Demand $7-.338.29 $6 468.69
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4 592.29 n/a
Energy Charge, per kWh
On-Peak 5.33055.61360
4.80794.67030
Mid-Peak 5.33054.21140
4.56634.14650
Off-Peak 4.76493.9101¢
4.37253.86470
PAYMENT
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 9-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 d-Third Revised Sheet No. 9-5
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 15-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 15-2
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 8210.95
85 7,200 $41.9511.67
200 18,000 $47.2714.38
FLOOD LIGHTING
LED Fixture
Watt (Maximum) Lumen (Minimum) Base Rate
85 8,100 $19.5016.14
150 18,000 $21 4717.03
300 32,000 $25.2822.42
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— OGto5er1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRaLFirst Revised Sheet No. 19-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-2
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: 011:00 p.m. to 710:00 pa.m. and 442:00 p.m. to 12:007:00 ap.m. Monday
through Saturday, except holidays
Off-Peak: 4210:00 a.m. to 02:00 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 -1210:00 pa.m., 42:00 p.m. to 5:00 p.m., and 8:00 p.m. to
406:00 pa.m. Monday through Saturday, except holidays
Off-Peak: l:nn A.m. to 6:00 a.m., 12:nn�r„ 4:00 p.m and 10:00 pa.m. to 4-2:00
ap.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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 19-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 19-3
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 $85-00110.00 $8500110.00
Basic Charge, per kW of
Basic Load Capacity $2.042.27 $2.042.27
Demand Charge, per kW of
Billing Demand $48.5014.46 $8-.4513.05
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4-.822.51 n/a
Energy Charge, per kWh
On-Peak 5 99415.95650
5.42044.98790
Mid-Peak 5.99414.50190
5.178334.47230
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—_ QGteber , 2-02-5January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 19-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 19-3
Off-Peak 5.42874.18940
4.98424.19500
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective--Q Gtebe, , 2-02-5January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 19-4
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 19-4
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $415.00450.00
$445-00450.00
Basic Charge, per kW of $2-.242.32 $2.242.32
Basic Load Capacity
Demand Charge, per kW of $10.0413.51 $8 6412.68
Billing Demand
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4.59-2.14 n/a
Energy Charge, per kWh
On-Peak 5 145.36940
4.7227-4.41120
Mid-Peak 5.23143.91450
4.48053.89600
Off-Peak 4 53.60180
4.28633.61870
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $415-00450.00
$445 00450.00
Basic Charge, per kW of
Basic Load Capacity $4-871.16 $4-871.16
Demand Charge, per kW of
Billing Demand $10.2015.19 $8-.7-913.37
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4 502.14 n/a
Energy Charge, per kWh
On-Peak 5 425.41730
4.6927-4.43240
Mid-Peak 5.21423.95290
4.45043.9169¢
Off-Peak 4.64513.6381¢
4.2561-3.63950
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-Octeber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 19-4
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 19-4
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised Sheet No. 19-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-5
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
ITT
neflr,: k ems
Company to provide new or reIGGated serviGe frern Substation FaGilities served by aR exiStiRg SeGtieR e
Transmisslen Fagilities with a Trnncmiccinn Vested Interest
Apploonnt is a SGhedule 19 Customer whose AppliGation requires the Gempany to provide new Gr
relOGated SeFViGe from SubstatiOR FaGilities served by TraRSMOSSOGR FaGilities that are free and Glear of
aRy Transmission Vested Interest
seniige from the Gemna y
GenneGted Load is the total nameplate MVV rating of the e'eGtF'G leadS GenneGted for SGhedule4g
seniine
f wires,
operated at a 34.5 Lilnvnit nr rotinn
SubstatmOR FaGol'toes iRGILjde these faGilotmes and related equipment that transform the voltage-of
energy from a 44 Lilnvnit nr higher rating to a 34.5 Liloyelt or lower rating
e e
and related equipmeRt that
operated at a 44 kilevelt or higher rating
Transmission Line installatmoe is any installation of new Transmission FaGilities owned by the
GempaR .
Additional SGhedule 19 AppliGant whenever Trans.rnission Lone Installation is built for that individual.
Transmission Vested interest is the right to a refund that an AppliGant or Additienal sGhedul
Rtteoh to that eotion of Tranccmis inn PaGil'tie
ccCri.Trcv�rrar�cccrvrrvr-rraTr..fri��n7rrracnT s.
4nnlirant for refs Rd to a Transmission Vested Interest I-Iolrler
Transmission Vested interest HpIdgE is a persen er entity that has paid a refundable Transmis i
Line Installatien (charge to the Gerona Ry for a Transmission Line Installatien
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36842 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRuary , 2-0-24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGGRd Third Revised Sheet No. 19-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 €first-Second Revised Sheet No. 19-6
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES AND/OR TRANSMISSION VESTED
INTEREST (GORtlRued)
Definitions (Continued)
Transmossmen Vested interest Portion us that part of the Company's transmiSSOGR System On w
a Transmission Vested Interact is held
Substation Allowance —
transfermeF GapaGity on Substation e
the following GeRsiderations will be ORGluded on the separate
agreement between the Customer and the Company:
�d beGause of the e
s request. The Customer will be eligible to reGelive a One tome
2--u-6-statien AllowanGe based upon subsequent sustained usage ef GaPaGity by the Gustern
a. SubstatmOR AIIniw"vaRGe The maximum possible i i- allnvwanGe will be
determined by multiplying the Gusterner's ar-Al lal inGFeaSe on lead by
826 per
�niill not evneed the anfi gal nnst of the Ci ihstatinn Canilities ' '
b. hs+ n Allewanoe Refi ends e S bstatinn Allewanr•e will he refunded
,n. tC}t�e,-r�-mvwurr�cr7. �,� a,-�
to the Customer over a five year period, with-anRual payments based OR the
e
BasiG Lead GapaGity at the time ef refund. The first refURd will be paid one year followl-R-9
the first month energy is delivered three ugh the new Substation Caoilities
The refURds will OGGUr based en the fellowing adjustment, whiGh will
added to the Substation /mince-ree'eiyed in the year. if then 's no
change in load from ear, the Substatien AllowaRGe fer thatyear
equal to the Substation anGe))from the nrn iio is dear:
((Change On lead 40M the pr i measured in MW)x(Substation AllowanGe per MW),)
Number of S uhs+afinn Allnuianno Rofiunrlo remaiRiRg in fivo_vear n nd
TheCustomer'sanni ial r inns will he made in a rdange with the
�aurT EE6rv-a-rTcc�r�rr�
Substation Allowance o int stated in separate nnnstnUntien agreement
�.rta-t�rr�-mvvvar-rc�a�vur�r�-cc�r err— epura
between the G istnmer and the Company.
Transmission Vested Interact
if a Schedule 19 Gusterner's request for — v eq-M res the installation of new or upgraded
feed,radial the following Gonsiderations will be inGluded on the separate agreement between the
Customer and the Gempany:
IDAHO Issued by IDAHO POWER COMPANY
Issued - Denemher 20 2 Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- Marnh 15, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
Order n� I3a52

Idaho Power Company Original First Revised Sheet No. 19-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 19-7
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
SPECIAL ARRANGEMENTS FOR SUBSTATION ALLOWANCES ANDIOR TRANSMISSION VESTED
INTEREST ( nntinued)
Transmission Vested Interest (Gentinued)
beGause of the The Gusterner will initially pay for the GGSt of new or upgraded TraRsrnissien FaGilities required
s request. The Gustemer may be eligible to reGeive Transmission Vested
iinterest Refunds uccorrdaRGe-wiih SGhed
Transmission Vested Interest Refunds
Transmission Vested interest Refund§ will be paid by the Gempany and funded b
aGGE)FdaRGe with SGhedule 19. The initial Applicant will be eligible te reGeive refunds up t
nernent of their original nenstn intion nest
Transmissien Vested Interest Qeft Rd Limitations
SGhedule 19 AppliGaRts duFiRg the 5 year peried following the completion date e
the Transmisslon I ine Installation
tirr�.
b.Irn nnnGGF staRGe will refs inns evreed 100 nernent of the refundable nertion of
aRy party's Gash payment to the GernpaRy.
Transmission Vested Interest Charges.Additional SGhedule 19 Applicants with a GORneGted Lead ef greater than 1 MVV
Transmission Vested interest Charge to be refunded te the TraRSMissien Vested interest Holder.
Transmission Vested interest Charge - 4 v B where•
,.,,.,,.� upi-,r,�rrn�.nvri--v-cvc �rrc , Lead
A - Lead Ratio: Additional SGhed�'l�9 ppliGantrr 's Ge rneGted Lea`tud divided by the siarmi-r
eead.
S— Vested interest Holder's refunded Gentrnbutk)n
Transmission Vested IRterest Holder remains the Transmission Vested IRterest Heider.
TraRSMOSSOGR Vested interest Holder's Transmission Vested interest will be reduGed by
Rewest Additional SGhedulee 19 ^A pp IliGQnt'lT'L meet.
The T - . . Vested interest Charge will not eXGeed the surn of the Transrn'SS'GR VeS
the TraRSM'ssion Vested interest Charges of the PFeViGUG F61le OF SGhed6i!e apply to the Additional
SGhedul 19 AppliGant.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36842 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRuary , 2-0-24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRaLFirst Revised Sheet No. 20-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-4
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: 611:00 p.m. to 710:00 pa.m. and 442:00 p.m. to 427:00 ap.m. Monday
through Saturday, except holidays
Off-Peak: 4210:00 a.m. to 32:00 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 4210:00 pa.m., 42:00 p.m. to 5:00 p.m., and 8:00 p.m. to
406:00 pa.m. Monday through Saturday, except holidays
Off-Peak: 4i:n�. to 6:00 a.m., 122:00 p.m. to n:00 p.m., and 10:00 pa.m. to 422:00
ap.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). If New Year's Day, Independence
Day, or Christmas Day falls on Sunday, the following Monday will be considered a holiday.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2-024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fifth Sixth Revised Sheet No. 20-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 €eFifth Revised Sheet No. 20-6
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 $340.00345.00
$340.00345.00
Basic Charge, per kW of $4-.&32.04 $4-.832.04
Basic Load Capacity
Demand Charge, per kW of $8-.912.68 $8�511.12
Billing Demand
Energy Charge, per kWh
On-Peak 7.62977.90580
6.73766.61220
Mid-Peak 7z3016.12660
5 77795.37360
Off-Peak 5.38824.54730
5.23954.74820
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $340.00345.00
$340.00345.00
Basic Charge, per kW of
Basic Load Capacity $4-.090.67 $4-.090.67
Demand Charge, per kW of
Billing Demand $7.828.93 $6 999.33
Energy Charge, per kWh
On-Peak 7.56658.15580
6.64606.81460
Mid-Peak 7.16696.35400
5.68625.57260
Off-Peak 5.31844.76990
5.14714.94550
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective OGteber 1, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fifth Sixth Revised Sheet No. 20-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 F Fifth Revised Sheet No. 20-7
SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)
MONTHLY CHARGE (Continued)
Large Power Service Rates
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $415.00450.00
$4155.00450.00
Basic Charge, per kW of $2.242.32 $2.242.32
Basic Load Capacity
Demand Charge, per kW of $49.5214.15 $�4213.32
Billing Demand
Energy Charge, per kWh
On-Peak 7.46227.86520
60.55566.5091¢
Mid-Peak 7.06266.01070
5.59525.27570
Off-Peak 5.21394.41520
5.05557-4.6531¢
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $445 00450.00
$415.00450.00
Basic Charge, per kW of
Basic Load Capacity $4.871.16 $4.871.16
Demand Charge, per kW of
Billing Demand $10.6815.83 $9-.2-614.01
Energy Charge, per kWh
On-Peak 7.44507.9131¢
60.52566.53030
Mid-Peak 7.04546.0491¢
5.565`1-5.29660
Off-Peak 5.19354.45150
5.02554.67390
PAYMENT
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber 1, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company i#th-Sixth Revised Sheet No. 20-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 €( Fifth Revised Sheet No. 20-7
The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— QGteber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company OkFirst Revised Sheet No. 20-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-8
SCHEDULE 20
SPECULATIVE HIGH-DENSITY LOAD
(Continued)
INTERRUPTION COMPENSATION
Fixed Capacity Reduction Rate:
Large General Service Rates $0.03330.0453 per kilowatt of reduction per event
hour
Large Power Service Rates $0.03820.0451 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.
Adiusted 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — danuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised Sheet No. 24-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 SeGen.d Qeyo-se deriginal Sheet No. 24-1
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 not been financially
responsible for an existing Schedule 24 service, 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 wA—begins on June 1 of each year and ends on
September 30 of each year. with the Customer's meter reading for the May Billing Perie d and eR d
the Gusterner's meter reading for the September Billing Peried. The beginRing GyCles of a Billing Peried
rnay aGtually be based on meter readiRgS taken not more thaR seven days prior to the start ef the
Gerrespenrdinn nolenrdar 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—jaRuary , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 24-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 24-3
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 $30.0035.00
$6 809.00
Demand Charge, per kW of
Billing Demand $15.06 16.50 n/a
Energy Charge
All kWh 6.12956.72220
7.20537.07520
TRANSMISSION SERVICE In-Season Out-of-Season
Service Charge, per month $445-00450.00
$6-.09.00
Demand Charge, per kW of
Billing Demand $44 2115.25 n/a
Energy Charge
All kWh 5.87276.30920
6.87546.6136¢
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber1,242-5January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFig+Ral First Revised Sheet No. 24-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst RevisecOriginal Sheet No. 24-4
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 shave
received two or more reminder notices for nonpayment during the most recent 12-month period
during which service was received, when the annual total billed amount on the Schedule 24
account(s) that received the reminder notices is greater than 15 percent of the total annual billed
amount on all Schedule 24 account(s), (2) have had service terminated for nonpayment during
the last four years and have not subsequently received Schedule 24 service, or awere 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— january , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal First Revised Sheet No. 24-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Forst RevisecOriginal Sheet No. 24-5
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 when the average of the Cumulative Past Due Balance is equal to or greater than
$750 per service point, or when the Cumulative Past Due Balance is equal to or greater than
10 000 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 Dust Due Balance
equal te-eF gFeateF tha^ $1,500 GR DeGembeF 31 Tier 2 Deposit during any of the previous four
years and who have not subsequently had active Schedule 24 service. The Company will allow
Payments for past due balances to be received up to five (5) days after December 31, without
requiring a Tier 2 Deposit. 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— january , 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Fifth Revised Sheet No. 26-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third-Fourth Revised Sheet No. 26-1
SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO
SPECIAL CONTRACT DATED MARCH 9, 2022, AMENDED APRIL 11, 2024
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
$3-373.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$47-.8321.04 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
$4—.3�991.248 per each kW over the Contract Demand.
Monthly Energy Charge
3-03942.7165¢ per kWh.
Embedded Energy Fixed Cost Charge
0.00000 per kWh of Renewable Resource On-Site Usage
Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos.1, 2, 3, and Second Revised Exhibit 1 of Micron's Special Contract, dated March
9, 2022, as amended.
Renewable Resource Cost
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Excess Generation Credit
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Administrative Charge
As defined in Second Revised Exhibit 1 of Micron's Special Contract, dated March 9, 2022, as
amended.
Pricing elements that rely on the most recently filed IRP are effective December 1, 2024,
pursuant to Order No. 36383 issued on November 8, 2024.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 5 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 29-1
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 29-1
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-.253.12 per kW of Contract Demand
Demand Charge,
$44-.&817.41 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW
Daily Excess Demand Charge
$4-.2-931.248 per each kW over the Contract Demand
Energy Charge
3.10062.73770 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octe;?er 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 30-1
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 30-1
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 $10.1714.49
2. Energy Charge, per kWh 4.24883.76990
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — October'I 202jJanuary 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal First Revised Sheet No. 31-1
Cancels
I.P.U.C. No. 30, Tariff No. 101Seventh RevisedOriginal Sheet No. 31-1
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 $3.142
Standby Facilities Contract Demand Charge
Per kW of Standby Facilities Contract Demand:
Paul Facility: $3-.452.72
Nampa Facility: $3-.472.74
Twin Falls Facility: $3-452.39
Standby Billing Demand Charge, per kW of
Standby Billing Demand $4�6.93
Excess Demand Charge
$1.248 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 20246 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 32-1
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 32-1
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 $3-393.12 $3-.383.12
Demand Charge
per kW of Billing Demand but no less
than the Contract Demand less 10,000 kW $19.6822.11 $16.2020.17
Daily Excess Demand Charge
per each kW over the Contract Demand $1.3191.248 $4.3191.248
Energy Charge
per kWh 3.04052.75200 3.28442.72020
Monthly Facilities Charge
Facilities installed beyond the Point of Delivery will be subject to the provisions of Rule M,
Facilities Charge Service.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775
Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcte;?er 1, 242-5January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 33-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Q4g+aa4-First Revised Sheet No. 33-1
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED MARCH 14, 2024
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: 311:00 p.m. to 7:00 pa.m. and 442:00 p.m. to 42-7:00 ap.m. Monday
through Saturday, except holidays
Off-Peak: 120:00 a.m. to 32:00 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 120:00 pa.m., 42:00 p.m. to 5:00 p.m., and 8:00 p.m. to 4-06:00
pa.m. Monday through Saturday, except holidays
Off-Peak: 42:n�. to 6:00 a.M., 12:nn�rto ^:n�—and 10:00 pa.m. to
42:00 ap.m. Monday through Saturday and all hours on Sunday and
holidays
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36383 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Never ber 9, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 33-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 33-2
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 $415.00450.00
$415.00450.00
Basic Charge, per kW of
Basic Load Capacity $4-.&71.16 $4-.871.16
Demand Charge, per kW of
Billing Demand $48.015.19 $8-.7913.37
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4302.14 n/a
Energy Charge, per kWh
On-Peak 5.21425.41730
4.6927-4.43240
Mid-Peak 5.21423.95290
4.45043.9169¢
Off-Peak 4.64513.6381¢
4.2561-3.63950
Embedded Energy Fixed Cost Rate, per kWh
On-Peak 1.00071.27520
1.82571.2451¢
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—October 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 33-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 33-2
Mid-Peak 1.00071.27520
1.8117-1.2451¢
Off-Peak 0.96031.27520
4.80051.2451¢
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 33-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 33-3
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
$4-.3291.248 per each kW over the Contract Demand.
Excess Generation Credit
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021
as amended.
Monthly Contract Demand Charge
$3-.283.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$22.29 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 Second 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 Second Revised Exhibit 3.1 of Brisbie,
LLC's Special Contract, December 22, 2021, as amended.
Supplemental Energy Cost
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021,
as amended.
Administrative Charge
As defined in Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, December 22, 2021,
as amended.
Pricing elements that rely on the most recently filed IRP are effective December 1, 2024, pursuant
to Order No. 36383 issued on November 8, 2024.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRal First Revised Sheet No. 34-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 34-2
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: 311:00 p.m. to 7-10:00 pa.m. and 442:00 p.m. to 427:00 ap.m. Monday
through Saturday, except holidays
Off-Peak: 120:00 a.m. to 23:00 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 120:00 pa.m., 42:00 p.m. to 5:00 p.m., and 8:00 p.m. to 4-06:00
pa.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 pa.m. to 422:00
ap.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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - January 1, 2-g24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 34-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 34-3
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 $415.00450.00
$415.00450.00
Basic Charge, per kW of
Basic Load Capacity $2.242.32 $2.242.32
Demand Charge, per kW of
Billing Demand $10.0413.51 $8-.6412.68
On-Peak Demand Charge, per kW of
On-Peak Billing Demand $4302.14 n/a
Energy Charge, per kWh
On-Peak 5 23145.18970
.7-22-7-4.24380
Mid-Peak 5 23443.73730
4.49053.72850
Off-Peak 4.-66553.42530
4.28633.45130
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.-36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective -Qcteber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Fourth Fifth Revised Sheet No. 34-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third-Fourth Revised Sheet No. 34-4
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
$4 3--91.248 per each kW over the Contract Demand.
Monthly Contract Demand Charge
$3-.393.12 per kW of Contract Demand.
Monthly Billing Demand Charge
$24.19 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.
Energy Charge
4.26380 per kWh of Block 2 Energy.
Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.-36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 40-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 40-2
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 10.00610.37100
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 $2.050
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 41-3
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 41-3
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 $12.3015.84
85 7,200 $44.317.05
140 10,800 $16.4318.54
200 18,000 $20.4421.46
Non-Metered Service—Variable Energy
Energy Charge, per kWh 10.00610.37100
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.
"B"— Customer-Owned, Idaho Power-Maintained System — Discontinued
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— OGto5er1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 41-4
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 41-4
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 (41 C)
Energy Charge, per kWh 6.7913.7494¢
Metered Service (41 CM)
Service Charge, per meter $5-.591.83
Energy Charge, per kWh 63.7494¢
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Octeber 1, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 42-1
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 42-1
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 7.8468.52930
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9l-First Revised Sheet No. 45-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Eighth Reyosed0riginal Sheet No. 45-3
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 $5-455.72 $6-455.72
Primary Service $5A35.77 $5435.77
Transmission Service $3 11 3.12 $3443.12
Standby Demand Charge, per kW of
Standby Billing Demand
Secondary Service $9-3511.33 $741-9.44
Primary Service $9-.3713.68 $9-.0912.55
Transmission Service $6-.-958.29 $6-098.69
Customers taking service under Schedule 19
Standby Reservation Charge, per kW of Summer Non-summer
Available Standby Capacity
Primary Service $6.705.98 $6.705.98
Transmission Service $3.11 3.12 $344 .12
Standby Demand Charge, per kW of
Standby Billing Demand
Primary Service $116915.46 $40.3114.76
Transmission Service $941-15.19 $8-.2-713.37
Customers taking service under Schedule 9 or Schedule 19
Excess Demand Charge
$1.248 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — danuar1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal First Revised Sheet No. 46-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Fifth Reyose'[Original Sheet No. 46-1
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-.592.86 per contracted kW of capacity
Mileage Charge
$0.0035 per kW per tenth of a mile in excess of 1.8 miles.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —January 1, 20246 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 54-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 94q+Ra1-First Revised Sheet No. 54-1
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, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General
Service).
Customers added to Idaho Power's system starting January 1, 20246, 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 $679.20907.64 $227.96280.10
Schedule 5 $679.20907.64 $227.96280.10
Schedule 6 $594.72799.60 $244.20293.77
Small General Service FCC FCC-Dist
Schedule 7 $174.96286.98 $24.0272.64
Schedule 8 $221.61325.39 $63.33107.18
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — danuary 1, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho
dymE;e No 24_nn

Idaho Power Company Third Fourth Revised Sheet No. 54-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 54-2
SCHEDULE 54
FIXED COST ADJUSTMENT
(Continued)
FIXED COST PER ENERGY RATE (Continued)
Residential FCE FCE-Dist
Schedules 1 and 3 6.16518.18380 per kWh
2.0692-2.52550 per kWh
Schedule 5— Summer On-Peak 16`269823.01840 per kWh
6.99899.48950 per kWh
Schedule 5— Mid-Peak 8134511.50940 per kWh
3 4904.74490 per kWh
Schedule 5— Summer Off-Peak 4.06755.75470 per kWh
1 7497-2.37240 per kWh
Schedule 5— Non-Summer On-Peak 7.79909.97800 per kWh
2.20592.4161¢ per kWh
Schedule 5— Non-Summer Off-Peak 5.19936.65190 per kWh
1.47051.61070 per kWh
Schedule 6 6.42949.08360 per kWh
2.64003.33720 per kWh
Small General Service FCE FCE-Dist
Schedule 7 3.84636.12330 per kWh
0.52021.54980 per kWh
Schedule 8 5.23087.33300 per kWh
1.49492.41550 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36617 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — '�;, 20225 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 54-2
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 54-2
The monthly Fixed Cost Adjustment for Residential Service (Schedules 1, 3, 5, and 6) is (0.0503)
cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is
(0.0614) cents per kWh.
EXPIRATION
The Fixed Cost Adjustment included on this schedule will expire May 31, 2026.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 7 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — '�;, 20225 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGend Third Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 55-2
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) 100 percent of the difference between the Projected Power Costs in Category 4
and the Base Power Costs in Category 4; 5) the Balancing Adjustment; and 6) Earnings Sharing. The
following table calculates the rates for Categories 1, 2, 3, and 4.
The following table shows the determination of PCA rates for Categories 1, 2, 3, and 4:
Base Projected Sharing
Category Description Power Power Difference % Rate
Cost Cost
(¢ per kWh)
The sum of fuel expense and
purchased power expense
(excluding purchases from
1
cogeneration and small power 1.6037130 1.89897 0.� 95/o 659 ° 0.2805056
producers), less the sum of off- 181 716 730
system surplus sales revenue and
revenue from market-based
special contract pricing.
Purchased power expense from 1.3216339 0.0777800 0.0777800
215
producers.
3
Demand response incentive 0.0658506 0.06695 0.00i1000 100/°° 0.001 i 000
payments. 008 687 687
Payments for battery energy 0.0000013 �0.�40660 �0.110660
4 storage system leases 279 0.11066 2213) 100% 2213)
2.9911989 0.4848058 0.4700455
Total 193 3.47599 406 420
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36618 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JUG, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGend Third Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 €i-st Second Revised Sheet No. 55-3
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.
Totals may not tie due to rounding.
Balancing Earnings Total PCA
Schedule Cateqory Adjustment Sharing
1 2 3 4
0.280556 0.0778002 0.00110 J0.1107 (0.3351) (0.0000) 0.2191
1 73 2 069 0221 043
0.56730. 0.0022" 0.00690-. (0.0221) (0.3351) (0.0000) 0.21919-43
3 2405 00U Q-4407 49
0.56730- 0.0022" 0.00690-. 0.0221 (0.3351) (0.0000) 0.21910-3
5 2405 778 0044 047 49
0.56730- 0.0022" 0.00690 0( 0221) (0.3350) (0.0000) 0.21920�3
6 2805 778 0044 0-4407 50
0.56730- 0.0022" 0.00690-. 0.0221 (0.3353) (0.0000) 0.21890�3
7 2405 77-8 0044 0:4 07 47
0.56730. 0.00220.0 0.00690 0( 0221) (0.3355) (0.0000) 0.21870 3
8 2ZO5 778 0014 04497 45
0.56730: 0.0022" 0.00690-. 0.0221 (0.3346) (0.0000) 0.2196043
9S 2Z05 778 0044 0.4 W 54
0.56730. 0.0022" 0.00690 0( 0221) (0.3350) (0.0000) 0.21920�3
9 P 2405 77-8 0041- 04497 50
0.56730- 0.0022" 0.00690 0.0221 (0.3349) (0.0000) 0.21930�3
9T 2Z05 77-8 0044 0:4 07 54
0.56730- 0.00220.0 0.00690 0( 0221) (0.3357) (0.0000) 0.21850 3
15 2905 778 00U 04 -0-7 40
0.56730: 0.0022" 0.00690 0( 0221) (0.3350) (0.0000) 0.21920�
19S 2Z05 778 0044 04107 50
0.56730- 0.0022" 0.00690 0( 0221) (0.3348) (0.0000) 0.21940-43
19P 2405 - 0044 041-97 52
0.56730- 0.0022" 0.00690-. 0.0221 (0.3348) (0.0000) 0.219404-3
19T 2805 77-8 0011 04407 52
0.56730- 0.0022" 0.00690 0( 0221) (0.3340) (0.0000) 0.22020-43
24 2805 778 0041- 0-4407 60
0.56730- 0.0022" 0.00690 0.0221 (0.3349) (0.0000) 0.21938 43
40 2Z05 778 0044 0:4 07 54
0.56730. 0.0022" 0.00690 0( 0221) (0.3354) (0.0000) 0.21880-43
41 2ZO5 779 0041- 04407 46
0.56730-. 0.0022" 0.00690 0.0221 (0.3352) (0.0000) 0.21900�3
42 2Z05 778 0044 044-97 48
0.56730. 0.0022" 0.00690 0( 0221) (0.3347) 0.21950-43
26 2SO5 779 0044 04497 53
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36618 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- du,,1, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGend Third Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 first Second Revised Sheet No. 55-3
0.56730. 0.0022" 0.00690 0.0221 (0.3348) 0.21940-1-3
29 2805 778 0044 9-44-97 52
0.56730. 0.0022" 0.00690 0( 0221) (0.3348) 0.21940�3
30 2805 779 0044- 0-41-N 52
0.56730. 0.0022" 0.00690 0.0221 (0.3348) 0.21940�3
32 280 778 0044- 0-4407 52
0.56730. 0.0022" 0.00690 OS 0221) (0.3348) 0.21940-43
34 280-5 778 0044- 0-4407 52
* 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
34 Lamb Weston $0.00
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 2026.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35618 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-iURe 1, 2025January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Third Fourth Revised Sheet No. 62-4
Cancels
I.P.U.C. No. 30, Tariff No. 101d-Third Revised Sheet No. 62-4
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 Com onent of the Retail E ergy Charge, per kWh
Time Period Secondary Service Primary Service Transmission Service
Summer On-Peak 4.8 1.8437 ¢ 4-.00 21.2551 ¢ -1.9 1.2752 ¢
Summer Mid-Peak 4.8 1.8437 ¢ 4-.00421.2551 ¢ -1.9 1.2752 ¢
Summer Off-Peak 4-:90411.8437 ¢ 0464 1.2551 ¢ 0-.96031.2752 ¢
Non-Summer On-Peak 4��1.8001 ¢ 4�91.2254 ¢ -1-.�1.2451 ¢
Non-Summer Mid-Peak 4�31.8001 ¢ 4�01.2254 ¢ 4-.�171.2451 ¢
Non-Summer Off-Peak 1�.v 1.8001 ¢ 4 81.2254 ¢ -1. 0 1.2451 ¢
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36775 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—Qcteber1,2 January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 91-First Revised Sheet No. 66-3
Cancels
I.P.U.C. No. 30, Tariff No. 101SeVeRth ReyisedOriginal Sheet No. 66-3
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 4-341.38% 9:640.64%
Schedule 15 4-.&21.74% 4-.&21.74%
Schedule 19 4-341.38% 8-.640.64%
Schedule 24 4-341.38% 9-.640.64%
Schedule 29 a.341.38% 9.640.64%
Schedule 32 4-.341.38% 0440.64%
Schedule 41 4431.17% 4431.17%
Schedule 45 4-341.38% &.640.64%
Schedule 46 4.341.38% &4 0.64%
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.
SCHEDULE 68
Monthly Maintenance Charge 0.64%
The monthly Maintenance Charge is determined by multiplying the Monthly Maintenance
Charge by the Company's investment in the System Protection, DER metering, and DER
communication equipment.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — danuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRaLFirst Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro RevoseeOriginal Sheet No. 68-1
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. DERs
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 or prospective 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.
Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator's behalf.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2G24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRaLFirst Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-2
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.
Incomplete Application is an application missing any information needed to satisfy the
requirements of the Customer Interconnection Process; including but not limited to, Customer Generator
signature, the application fee, and details about the Generation Facility.
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—_ january 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Or+ginalFirst Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro RevisecOriginal Sheet No. 68-4
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,
including the Company's Customer Requirements for Electric Service (found at
idahopower.com/requirements), 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, settings, 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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— jaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral First Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro RevoseeOriginal Sheet No. 68-8
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (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 from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customers
Generator without existing retail service that has not completed the Customer Generator Interconnection
Process requirements by the requested project in-service date identitifed on the completed application
will be considered expired.
Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revosed0riginal Sheet No. 68-8
CVQTC-A 114II—DIFI(' —.KIQ
Ay tE) ellel—, --Stemns hat the Total Nameplate
purposes of this seh
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revosed0riginal Sheet No. 68-8
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)
SYSTEM MODIFICATIONS
1. Any modifications to Customer Generator Systems that increase the Total Nameplate
Capacity of the system or modify the system in anyway(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 schedule.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuaFy 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRaLFirst Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-9
SYSTEM MODIFICATIONS (C
2. Customer Generators planning to make system modifications must submit an application,
a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Original First Revised 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. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuaFy 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company QFigiRalFirst Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-9
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)
UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)
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 Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuaFy 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral First Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisecOriginal Sheet No. 68-10
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 DERs with Total Nameplate Capacity less than 3 MVA.
APPLICATION PROCESS
Customers Generators requesting to interconnect a DER less than 3 MVA are required to
complete the following application process prior to interconnection:
1. Customers Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company's website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.
2. Upon receipt of a completed application and a $100 non-refundable 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 202-4January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral First Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Reyise`lOriginal Sheet No. 68-10
des are nee&ssa:ry
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r+giRalFirst Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ctrs+ ReviseelOriginal Sheet No. 68-10
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)
If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.
If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.
3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
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. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company's evaluation for Upgrades for new customers
conducted in compliance with Rule H — New Service Attachments and Distribution Line Installations or
Alterations.
a. If the results of the Feasibility_ Review indicate satisfactory system capability—the
the
Company will provide the Customer with an official "Approval to Proceed" notification.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuaFy 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral First Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-11
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 provide the Customer with a Feasiblity Study Agreement which requires a deposit of$1,000
and must be signed and returnedperforrn the Feasibility c within fifteen 151 business days. Upon
receipt of the signed Feasibility Study Agreement and deposit, the Company will perform the Feasiblity
Study within thirty (30) 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. The Feasibilty Study AgreerneRt ORGl Imes a deposit
of$1,880.At the Company's discretion, additional studies referenced in Section 4 may be applicable.
a. Installation and funding of the construction, installation, and maintenance of
required Protection Equipment will be subject to the following provisions:
than 500 kVA Total Nameplate Gapaenty will require additional Gempany Furnis
I.A.1he-A it
shall pay t1le actual 60ssts of all Feq-bJ!.__
on Equipment prier to the
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r+giRal First Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Ciro Rey'sedOriginal Sheet No. 68-12
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)
i. Protection Equipment Requirements (Rotating Machined: 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 areater
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-bv-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 ofo,--nv5v
s ecified in Schedule 66 er month times the investment in the Protection
Eauigment.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r+gi First Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 Corot RevosecOriginal Sheet No. 68-12
f. Documentation of the meter number and system configuration.
11
GA site- i-Aspeetion dw
6A8 OF th- eenditions- not being met that
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9Fig+Ral First Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Rey'sedOriginal Sheet No. 68-13
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)
9. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.
7. A return trip charge of$52.00 will be billed to the Customer each time Company personnel
are dispatched to the fob 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 mRstal•IerCustomer's
Representative, as identified 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. The rate change-. '. '�OO
&GUmstanGes will the rate Ghange GGGUF mere thaR fifteeR (15) busiRess days fre... III.- date of the
oUGGeSSfUlly ,..,r~ pleted ;- pection.wfll be no later than the Customer's next Billing Period following their
successfully completed inspection. Upon completion of this process, the Customer will receive
confirmation that the application process has been successfully completed.
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.
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS
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.The capacity of an Energy Storage Device shall
not be used to calculate the 25 kVA capacity limit but will be used to calculate Total Nameplate Capacity
for the Feasbility Review.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective- JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9r+giRal First Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 First ReviseelOriginal Sheet No. 68-13
AIlIAI CY�(l�T !`_NTR QVQT_.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company QF atFirst Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisecOriginal Sheet No. 68-14
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)
NON E PORT CONTROL SYSTEM (GontoRued)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 Mmanagement Ssystem, 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.
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:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 20224January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Origia4First Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 First ReviseclOriginal Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— daRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company GFigiRaLFirst Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisecOriginal Sheet No. 68-15
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)
UNAUTHORIZED INADVERTENT EXPORT (Continued)
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 (off)
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.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2G24January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company 9rigiRal First Revised Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Reyosed0riginal Sheet No. 68-18
SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)
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 PeFGer++as specified in Schedule 66 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
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
This Uniform Customer Generator Interconnection Agreement ("Agreement") is entered to be
effective as of the day of 1 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.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 R 36 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— JaRuary 1, 2024January 1, 2026 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Second Revised Sheet No. 84-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 9F+4a1 First Revised Sheet No. 84-2
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
APPLICABILITY (Continued)
ii. Single-Meter Interconnection (applicable to new applicants effective
December 2, 2020): Owns and/or operates a Generation Facility 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 a single meter.
6. The Generation Facility must have a total nameplate rating equal to or less than the
greater of: (a) the greatest monthly Billing Demand established during the most recent 12-month period
at the time of applying for interconnection, which includes and ends with the most recent Billing Period,
or (b) 100 kW. The capacity of an Energy Storage Device shall not be used to calculate the capacity
limits in this schedule.
a. Subject to the Company's discretion and approval, for a Customer applying to
interconnect a Generation Facility (1) where 12-months of Billing Demand is not available, or (2)
where the Billing Demand is not reflective of future operations, the customer may provide
evidence that the proposed Generation Facility meets the applicability of this schedule in
accordance with one of the following:
i. Schedules 9 and 19:
ai. If previous billing data is available for the premises and the
Customer's electrical needs are similar to the previous customer, the Company may rely
on available historical Billing Demand at the premises not to exceed the previous 12
months.
bi if the Customer has another account in the Company's service
area with similar electrical needs, the Company may rely on available historical Billing
Demand from that account not to exceed the previous 12 months.
C. The Customer can have a third-party currently licensed or
registered professional engineer provide analysis and documentation detailing the
electrical load requirements for the Customer which support the requested load or an
increase in demand expected to occur within the next 12 m„n+hc
ii. Schedule 24:
a. If historical Billing Demand is available for the Premises and is still
reflective of expected operations, the Company will rely on the maximum of the most
recently available 12-months of Billing Demand.
b iv. For newly installed equipmenta Customer tan k in retai �Ge
any' Reds le 24, the Customer may submit documentation of the hor�se�power ("HP")
of the irrigation equipment (motors and/or pumps). Based on the submitted
IDAHO Issued by IDAHO POWER COMPANY
Issued —jU,e-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8, ` 02- January 1, 2026 1221 West Idaho Street, Boise, Idaho
nd„ino Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 94a4-First Revised Sheet No. 84-2
documentation, the Company will determine the maximum continuous HP using
a conversion factor of 1 HP to 0.8 kW to define the demand for the Point of Delivery.
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August R 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+ral-First Revised Sheet No. 84-3
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
APPLICABILITY (Continued)
7. Legacy Status for eligible Exporting Systems will terminate on December 1. 2045.
8. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the
premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System
taking service under Schedule 84 will be responsible for complying with the terms and conditions of the
on-site generation service in effect for that premises.
9. A Legacy System that is offline for over six (6) months or that is moved to a different site
shall forfeit Legacy Status of the Exporting System.
10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy
System 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
Legacy System beyond these limits and wishes to maintain Legacy Status for the original system, the
new portion of the DER shall be separately metered and would not qualify for Legacy Status.
11. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the
Legacy Status of the Generation Facility.
12. A Customer with a Legacy System may elect to forfeit the system's Legacy Status by
submitting the request to the Company in writing. A Customer forfeiting Legacy Status will be required
to reconfigure to a single-meter system.
DEFINITIONS
Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum
use during the Billing Period, adjusted for Power Factor.
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.
Exported Energy means all kWh generated by a Customer in excess of the Customer's on-site
consumption that is exported to the Company's system.
IDAHO Issued by IDAHO POWER COMPANY
Issued Per Order No.--June-?,z024 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8, 2 January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 04q+r a-First Revised Sheet No. 84-3
design he --f eleetri- energy to the Gempany I'm Experfing System
sys applicable
IDAHO Issued by IDAHO POWER COMPANY
Issued Per Order No.--Ju4e4-7, 29Zz4 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8, ` 02- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+ral-First Revised Sheet No. 84-4
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
DEFINITIONS (Continued)
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.
Financial Credit represents the amount in dollars carried forward to offset Monthly Charges in a
subsequent Billing Period. A Financial Credit is generated during a Billing Period when the product of
Exported Energy and the Export Credit Rate exceeds a Customer's Monthly Charges.
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.
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 DER to the
Point of Delivery or Generation Interconnection Point.
Kilowatt-Hour Credit ("kWh Credit") is the accumulated Excess Net Energy that is carried forward
to offset energy usage in a subsequent Billing Period.
Legacy Status refers to the ability for a system to receive Net Energy Metering, including net
monthly one-for-one kWh credit compensation for Excess Net Energy.
Legacy Systems means any system that meets the applicable criteria as described in Order Nos.
34509, 34546, 34854 and 34892.
Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a
Legacy System. Net Billing will be effective with each eligible customer's first billing cycle after January 1,
2024.
Net Energy Metering is the compensation structure applicable to all Legacy Systems.
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.
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 04gi.a-First Revised Sheet No. 84-4
nnnniTui v Qii i ini�
V _rv_nn E IAI III _..T.___ _. of io—H, nN
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+na4-First Revised Sheet No. 84-5
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
DEFINITIONS (Continued)
Schedule 68 is the Company's service schedule which provides for interconnection to DERs or its
successor schedule(s) as approved by the Commission.
MONTHLY BILLING
The Customer shall be billed in accordance with the Customer's applicable standard service
schedule, including appropriate monthly charges, and the Export Credit Rate under this schedule.
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to all transactions for Net Energy Metering under this
schedule.
1. Balances of generation and usage by the Customer:
NET ENERGY METERING CONDITIONS OF PURCHASE 4nln e8 C (Gentinued)
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. 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 sCredit to offset energy usage in a
subsequent Billing Period. EXGess Net Enern„kWh sCredits are subject to the following
provisions:
i. kWh 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. kWh Credits shall carry forward provided the Customer maintains electric
service at the same Point of Delivery.
iii. kWh 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 kWh sCredits will expire at the time the final bill is prepared.
2. Aggregation of meters for the annual transfer of unused EXGess Net Epor kWh sCredits:
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order Notes-17, 2024. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August Q '^'^January 1, 2026 1221 West Idaho Street, Boise, Idaho
AdViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 04gi al-First Revised Sheet No. 84-5
a. If a balance of EXGess Net Eger^"kWh CGredits exists at a Designated Meter, the
Customer may request to transfer the unused kWh sCredits to offset energy consumption at
eligible meters. A meter is eligible for aggregation if it meets all of the following criteria:
Designated Fem the purposes of this tariff, eentiguous preparty
The motor sewed bN as the Desinnated Me
and
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order Nome-17, 2024. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August Q '^'^January 1, 2026 1221 West Idaho Street, Boise, Idaho
d Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 04gi aLFirst Revised Sheet No. 84-6
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued)
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
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, kWh
eCredits 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, kWh
eCredits may only be transferred to meters taking service under Schedule 9, Schedule 19,
or Schedule 24.
b. Customers may submit requests to transfer EXGess Net Energy kWh eCredits
between December 1 and January 31 of each year. All requests must be received by Idaho
Power by midnight, Mountain Stanl+aFd Timo on or before January 31. If a Customer does not
request to transfer EXGess Net F=Re gykWh eCredits by the January 31 submission deadline
Excess Net Energy/kWh Credits will carry forward to offset consumption at the Designated Meter
until they become eligible the following year.
C. Requests to transfer EXGess Net ERergykWh eCredits must be executed by the
Company no later than March 31. Transfers will be based on the balance of EXGess e
En�nergykWh Credits available at the time the transfer is made.
d. If multiple meters are eligible for aggregation, EX^^^^ Net Enor,."kWh eCredits
must first be applied to the Designated Meter, then to eligible meters on 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.
NET BILLING—CONDITIONS OF PURCHASE AND SALE
The conditions listed below shall apply to transactions for Net Billing under this schedule.
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 04gi a-First Revised Sheet No. 84-6
1. Balances of usage and exports by the Customer.
he" ageorda--a-
AAFFAA
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— August 8 ` 02- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dV'Ge nip 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+ral-First Revised Sheet No. 84-7
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET BILLING—CONDITIONS OF PURCHASE AND SALE (Continued)
a. The Customer shall be billed for the electricity supplied by the Company at the
rates contained within the Customer's applicable standard service schedule, in accordance with
normal metering practices.
b. The Customer shall be credited for Exported Energy at the applicable Export
Credit Rate contained within this schedule as a credit in dollars to only offset Monthly_ Charges.
EX9040d F"er^14Financial-G Credits are subject to the following provisions:
i. Financial Credits shall carry forward provided the Customer maintains
electric service at the same Point of Delivery.
ii. Financial Credits are transferrable in the event that a Customer
relocates. If the establishment of service at the new Point of Delivery is not initiated at
the time service at the Designated Meter is discontinued, it is the G us+omor's
responsibility to request the Gredit transfer when serviGe is established at the nev.f
10Gation in Idaho PE)Wer's eFViG8 y unused Financial Credits will be paid out
following the time the final bill is prepared.
a G is+omor dic n+ini es SerVino a+ the point of Delivery assoniated
�. �i-rrn-racv�cTaTc�ar-crr� ..ivcrcrcca
with the Exporting System and does net intend to establish seFViGe at anether IoGati
idahe Power's seFVIGe area aRy unused Gredits will be paid eut fellewing the tome the
final hill is prepared
2. Aggregation of meters for the annual transfer of unused Financial ECredits:
a. If a balance of Financial GCredits exists at a Designated Meter, the Customer
may request to transfer the unused Financial GCredits to eligible meters. A meter is eligible for
aggregation if it meets the following criteria:
i. The account subject to offset is held by the Customer; and
ii. The electricity recorded by the meter is for the Customer's requirements.
b. Customers may submit requests to transfer a stated percentage of available
Financial GCredits between December 1 and January 31 of each year. All requests must be
received by Idaho Power by midnight, Mountain Standard Time on or before January 31. If a
Customer does not request to transfer Financial GCredits by the January 31 submission
deadline Financial GCredits will carry forward at the Designated Meter until they become eligible
for transfer the following year.
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dVino Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+ral-First Revised Sheet No. 84-7
C. Requests to transfer Financial eCredits must be executed by the Company no
later than March 31. Transfers will be based on the balance of Financial GCredits available at
the time the transfer is made.
d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.
NET ENERGY METERING & NET BILLING— GENERAL CONDITIONS
1. The Customer shall never deliver or attempt to deliver energy to the Company's system
when the Company's system serving the Customer's DER is de-energized for any reason.
IDAHO Issued by IDAHO POWER COMPANY
Issued june-17, 2024Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2

Idaho Power Company Forst Second Revised Sheet No. 84-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 94g+ral-First Revised Sheet No. 84-8
SCHEDULE 84
LARGE GENERAL, LARGE POWER, AND IRRIGATION
ON-SITE GENERATION SERVICE
(Continued)
NET ENERGY METERING & NET BILLING — GENERAL CONDITIONS (Continued)
2. 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 iniurv, including death, to any third party.
3. The Customer is responsible for all costs associated with the DER 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 DER in order to maintain a safe, reliable electrical system.
4. 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.
5. 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.
6. 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.
7. 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 Issued by IDAHO POWER COMPANY
Issued june-17, 2024 Per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—August 8 202- January 1, 2026 1221 West Idaho Street, Boise, Idaho
dViGe Ne 24_n2