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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

EXCHANGE ACT OF 1934

For the quarterly period ended

June 30, ~~2022~~2023

☐

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

EXCHANGE ACT OF 1934

For the transition period from __________ to __________

Exact name of registrants as specified

I.R.S. Employer

Commission File

in their charters, address of principal

Identification

Number

executive offices, zip code and telephone number

Number

1-14465

IDACORP, Inc.

82-0505802

1-3198

Idaho Power Company

82-0130980


1221 W. Idaho Street
Boise,		Idaho		83702-5627
	(208)		388-2200

State of Incorporation:

Idaho

None

Former name, former address and former fiscal year, if changed since last report.

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	IDA	New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

IDACORP, Inc.: Yes X ☒No __☐ Idaho Power Company: Yes X ☒No __☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).

IDACORP, Inc.: Yes X ☒No __☐ Idaho Power Company: Yes X ☒ No __☐

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers, smaller reporting companies, or emerging growth companies. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act:

IDACORP, Inc.:

Large accelerated filer X ☒Accelerated filer __☐ Non-accelerated filer __

☐ Smaller reporting company ☐

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange

Act. __☐

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Idaho Power Company:

Large accelerated filer __☐ Accelerated filer __☐ Non-accelerated Filer X☒

Smaller reporting company ☐

Emerging growth company ☐

Act. __

☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act).

IDACORP, Inc.: Yes ☐ No X ☒ Idaho Power Company: Yes ☐ No X☒

Number of shares of common stock outstanding as of July ~~29, 2022:~~28, 2023:

IDACORP, Inc.: ~~50,560,040~~50,614,789

Idaho Power Company: 39,150,812, all held by IDACORP, Inc.

This combined Form 10-Q represents separate filings by IDACORP, Inc. and Idaho Power Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Idaho Power Company makes no representations as to the information relating to IDACORP, Inc.’s other operations.

Idaho Power Company meets the conditions set forth in General Instruction (H)(1)(a) and (b) of Form 10-Q and is therefore filing this report on Form 10-Q with the reduced disclosure format.

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TABLE OF CONTENTS
				Page
Commonly Used Terms				4
Cautionary Note Regarding Forward-Looking Statements				5

Part I. Financial Information

	Item 1. Financial Statements (unaudited)
		IDACORP, Inc.:
			Condensed Consolidated Statements of Income	7
			Condensed Consolidated Statements of Comprehensive Income	8
			Condensed Consolidated Balance Sheets	9
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Statements of Equity	12
		Idaho Power Company:
			Condensed Consolidated Statements of Income	13
			Condensed Consolidated Statements of Comprehensive Income	14
			Condensed Consolidated Balance Sheets	15
			Condensed Consolidated Statements of Cash Flows	17
		Notes to Condensed Consolidated Financial Statements		18
		Reports of Independent Registered Public Accounting Firm - Deloitte & Touche LLP		3334
	Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			3536
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			6361
	Item 4. Controls and Procedures			6562

Part II. Other Information

	Item 1. Legal Proceedings			6664
	Item 1A. Risk Factors			6664
	Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			6664
	Item 3. Defaults Upon Senior Securities			6664
	Item 4. Mine Safety Disclosures			6664
	Item 5. Other Information			6664
	Item 6. Exhibits			6765

Signatures				6866

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COMMONLY USED TERMS

The following select abbreviations, terms, or acronyms are commonly used or found in multiple locations in this report:

~~2021~~2022 Annual Report	-	IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2021~~2022
ADITC	-	Accumulated Deferred Investment Tax Credits
AFUDC	-	Allowance for Funds Used During Construction
AOCI	-	Accumulated Other Comprehensive Income
BCC	-	Bridger Coal Company, a joint venture of IERCo
~~BLM~~	-	~~U.S. Bureau of Land Management~~
BPA	-	Bonneville Power Administration
~~CEQ~~	-	~~Council on Environmental Quality~~
CWA	-	Clean Water Act
EIS	-	Environmental Impact Statement
EPA	-	U.S. Environmental Protection Agency
~~ESA~~	-	~~Endangered Species Act~~
FCA	-	Fixed Cost Adjustment
FERC	-	Federal Energy Regulatory Commission
HCC	-	Hells Canyon Complex
IDACORP	-	IDACORP, Inc., an Idaho corporation
Idaho Power	-	Idaho Power Company, an Idaho corporation
Idaho ROE	-	Idaho-jurisdiction return on year-end equity
Ida-West	-	Ida-West Energy Company, a subsidiary of IDACORP, Inc.
IERCo	-	Idaho Energy Resources Co., a subsidiary of Idaho Power Company
IFS	-	IDACORP Financial Services, a subsidiary of IDACORP, Inc.
IPUC	-	Idaho Public Utilities Commission
IRP	-	Integrated Resource Plan
Jim Bridger plant	-	Jim Bridger ~~generating~~power plant
kWh	-	Kilowatt-hour
MD&A	-	Management’s Discussion and Analysis of Financial Condition and Results of Operations
MW	-	Megawatt
MWh	-	Megawatt-hour
NAV	-	Net asset value
~~NEPA~~	-	~~National Environmental Policy Act~~
~~NMFS~~	-	~~National Marine Fisheries Service~~
O&M	-	Operations and Maintenance
OATT	-	Open Access Transmission Tariff
OPUC	-	Public Utility Commission of Oregon
PCA	-	Idaho-Jurisdiction Power Cost Adjustment
PCAOB	-	Public Company Accounting Oversight Board (United States)
PURPA	-	Public Utility Regulatory Policies Act of 1978
RFP	-	Request for Proposals
SEC	-	U.S. Securities and Exchange Commission
~~SIP~~	-	~~State Implementation Plan~~
SMSP	-	Security Plan for Senior Management Employees
~~Term Loan Facility~~	-	~~Term Loan Credit Agreement~~
~~USACE~~	-	~~U.S. Army Corps of Engineers~~
USFWS	-	U.S. Fish and Wildlife Service
Valmy plant	-	Idaho Power's jointly-owned coal-fired generating plant in Valmy, Nevada
~~Western EIM~~	-	~~Energy imbalance market in the western United States~~
WMP	-	Wildfire Mitigation Plan
WOTUS	-	Waters of the United States
~~WPSC~~WRAP	-	~~Wyoming Public Service Commission~~Western Resource Adequacy Program

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

In addition to the historical information contained in this report, this report contains (and oral communications made by IDACORP, Inc. (IDACORP) and Idaho Power Company (Idaho Power) may contain) statements that relate to future events and expectations, such as statements regarding projected or future financial performance, cash flows, capital expenditures, dividends, capital structure or ratios, load forecasts, strategic goals, challenges, objectives, and plans for future operations. Such statements constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, or future events, or performance, often, but not always, through the use of words or phrases such as "anticipates," "believes," "could," "estimates," "expects," ~~"guidance,"~~ "intends," "potential," "plans," "predicts," "preliminary," "projects," "may," "may result," "may continue," or similar expressions, are not statements of historical facts and may be forward-looking. Forward-looking statements are not guarantees of future performance and involve estimates, assumptions, risks, and uncertainties that may differ materially from actual results, performance, or outcomes. In addition to any assumptions and other factors and matters referred to specifically in connection with such forward-looking statements, factors that could cause actual results or outcomes to differ materially from those contained in forward-looking statements include those factors set forth in this report, IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2021,~~2022, particularly Part I, Item 1A - "Risk Factors" and Part II, Item 7 - "Management’s Discussion and Analysis of Financial Condition and Results of Operations" of that report, subsequent reports filed by IDACORP and Idaho Power with the U.S. Securities and Exchange Commission (SEC), and the following important factors:

•decisions by the Idaho and Oregon public utilities commissions and the Federal Energy Regulatory Commission that impact Idaho Power's ability to recover costs and earn a return on investment;

•changes to or the elimination of Idaho Power's regulatory cost recovery mechanisms;

•expense and risks associated with capital expenditures for, and the permitting and construction of, utility infrastructure projects that Idaho Power may be unable to complete or that may not be deemed prudent by regulators for full cost recovery or full return on investment;

•expenses and risks associated with supplier and contractor delays and failure to satisfy project quality and performance standards, on utility infrastructure projects and the potential impacts of those delays on Idaho Power's ability to serve customers;

•power demand exceeding supply, and the rapid addition of new industrial and commercial customer load and the volatility of such new load demand, resulting in increased costs for purchasing energy and capacity in the market, if available, or acquiring or constructing additional generation and transmission resources, and battery storage facilities;

•impacts of economic conditions, including an inflationary or recessionary environment and increasing interest rates, on items such as operations and capital investments, supply costs and delivery delays, supply scarcity and shortages, population growth or decline in Idaho Power's service area, changes in customer demand for electricity, revenue from sales of excess power, credit quality of counterparties and suppliers and their ability to meet financial and operational commitments, and collection of receivables;

•changes in residential, commercial, and industrial growth and demographic patterns within Idaho Power's service area, and the associated impacts on loads and load ~~growth,~~growth;

•employee workforce factors, including the operational and financial costs of unionization or the attempt to unionize all or part of the companies’ workforce, the cost and ability to attract and retain skilled workers and third-party contractors and suppliers, the cost of living and the ~~availability~~related impact on recruiting employees, and the ability to adjust to fluctuations in labor costs;

•changes in, failure to comply with, and costs of ~~regulatory mechanisms that allow for timely cost~~compliance with laws, regulations, policies, and orders including those relating to reliability and security, the environment, climate change, natural resources, and threatened and endangered species, and associated mitigation requirements, which may result in penalties and fines, increase compliance and operational costs, and impact recovery ~~of those changes~~associated with increased costs through ~~customer~~ rates;

•abnormal or severe weather conditions (including conditions and events associated with climate change), wildfires, droughts, earthquakes, and other natural phenomena and natural disasters, which affect customer sales, hydropower generation, ~~levels,~~ repair costs, service interruptions, liability for damage caused by utility property, and the availability and cost of fuel for generation plants or purchased power to serve customers;

•advancement of self-generation, energy storage, energy efficiency, alternative energy sources, and other technologies that may reduce Idaho Power's sale or delivery of electric power or introduce operational ~~or cyber-security~~ vulnerabilities to the power grid;

•~~expense and risks associated with capital expenditures for, and the permitting and construction~~Table of ~~utility infrastructure that Idaho Power may be unable to complete or that may not be deemed prudent by regulators for cost recovery or a return on investment;~~Contents

•power demand exceeding supply, resulting in increased costs for purchasing energy and capacity in the market, if available, or acquiring or constructing additional generation resources and battery storage facilities;

•variable hydrological conditions and over-appropriation of surface and groundwater in the Snake River Basin, which may impact the amount of power generated by Idaho Power's hydropower facilities;

•~~Idaho Power's~~ ability to acquire fuel, power, electrical equipment, and transmission capacity on reasonable terms and prices, particularly in the event of unanticipated or abnormally high resource demands, price volatility, lack of physical availability, transportation constraints, outages due to maintenance or repairs to generation or transmission facilities, disruptions in the supply chain, or credit quality or a lack of ~~credit of counterparties~~counterparty and ~~suppliers;~~supplier credit;

•disruptions or outages of Idaho Power's generation or transmission systems or of any interconnected transmission systems, which can result in liability for Idaho Power, increase power supply costs and repair expenses, and reduce revenues;

•accidents, electrical contacts, fires (either affecting or caused by Idaho Power facilities or infrastructure), explosions, infrastructure failures, general system damage or dysfunction, and other unplanned events that may occur while operating and maintaining assets, which can cause unplanned outages; reduce generating output, damage company assets, operations, or reputation; subject Idaho Power to third-party claims for property damage, personal injury, or

~~Table of Contents~~

loss of life; or result in the imposition of fines and ~~penalties~~penalties; insurance coverage for ~~which~~such operating and event risks is subject to the terms and limitations of the available policies and may not be sufficient in amount to cover Idaho ~~Power may have inadequate insurance coverage~~;Power’s ultimate liability;

•acts or threats of terrorist incidents, acts of war, social unrest, cyber or physical security attacks, and other malicious acts of individuals or groups seeking to disrupt Idaho Power's operations or the electric power grid or compromise data, or the disruption or damage to the companies’ business, operations, or reputation resulting from such ~~events~~;events;

•increased purchased power costs and operational and reliability challenges associated with purchasing and integrating intermittent renewable energy sources into Idaho Power's resource portfolio;

•ongoing impacts of COVID-19 and its variants, and government mandates related to COVID-19 vaccines, masking, and testing, on the global and regional economy and on Idaho Power’s employees, customers, contractors, and suppliers, including on loads and revenues, uncollectible accounts, transmission revenues, supply chain availability, attrition of skilled workers, and other aspects of the economy and the companies’ business;

•Idaho Power’s concentration in one industry and one region, and the resulting exposure to regional economic conditions and regional legislation and regulation;

•employee workforce factors, including the operational and financial costs of unionization or the attempt to unionize all or part of the companies’ workforce, the cost and ability to attract and retain skilled workers and third-party contractors, the cost of living and the related impact on recruiting employees, and the ability to adjust to fluctuations in labor costs;

•failure to comply with state and federal laws, regulations, and orders, including interpretations and enforcement initiatives by regulatory and oversight bodies, which may result in penalties and fines and increase the cost of compliance and remediation;

•changes in tax laws or related regulations or interpretations of applicable laws or regulations by federal, state, or local taxing jurisdictions, and the availability of tax ~~credits, and the tax rates payable by IDACORP shareholders on common stock dividends;~~

•adoption of, changes in, and costs of compliance with, laws, regulations, and policies relating to the environment, climate change, natural resources, and threatened and endangered species, and the ability to recover associated increased costs through rates;credits;

•inability to timely obtain and the cost of obtaining and complying with required governmental permits and approvals, licenses, rights-of-way, and siting for transmission and generation projects and hydropower facilities;

•~~failure to comply with mandatory reliability and cyber and physical security requirements, which may result in penalties, reputational harm, and operational changes;~~

•ability to obtain debt and equity financing or refinance existing debt when necessary and on ~~favorable~~satisfactory terms, which can be affected by factors such as credit ratings, reputational harm, volatility or disruptions in the financial markets, interest rate fluctuations, decisions by the Idaho or Oregon public utility commissions, and the companies' past or projected financial performance;

•ability to enter into financial and physical commodity hedges with creditworthy counterparties to manage price and commodity risk for fuel, power, and transmission, and the failure of any such risk management and hedging strategies to work as ~~intended;~~intended, and the potential losses the companies may incur on those hedges, which can be affected by factors such as the volume of hedging transactions and degree of price volatility;

•changes in actuarial assumptions, changes in interest rates, increasing health care costs, and the actual and projected return on plan assets for pension and other post-retirement plans, which can affect future pension and other postretirement plan funding obligations, costs, and liabilities and the companies' cash flows;

•~~assumptions underlying the coal mine reclamation obligations at Bridger Coal Company and related funding and bonding requirements, and the~~ remediation costs associated with planned exits from participation in Idaho Power's co-owned coal plants;

•ability to continue to pay dividends and achieve target dividend payout ratios based on financial performance, capital requirements, and in light of credit rating considerations, contractual covenants and restrictions, and regulatory limitations; and

•adoption of or changes in accounting policies and principles, changes in accounting estimates, and new SEC or New York Stock Exchange requirements or new interpretations of existing requirements.

Any forward-looking statement speaks only as of the date on which such statement is made. New factors emerge from time to time and it is not possible for management to predict all such factors, nor can it assess the impact of any such factor on the business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement. IDACORP and Idaho Power disclaim any obligation to update publicly any forward-looking information, whether in response to new information, future events, or otherwise, except as required by applicable law.

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PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

IDACORP, Inc.

Condensed Consolidated Statements of Income

(unaudited)


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in thousands, except per share amounts)				(in thousands, except per share amounts)					(in thousands, except per share amounts)				(in thousands, except per share amounts)
Operating Revenues:	Operating Revenues:									Operating Revenues:
Electric utility revenues	Electric utility revenues	$	357,668	$	359,058	$	701,589	$	674,625	Electric utility revenues	$	412,727	$	357,668	$	842,065	$	701,589
Other	Other	1,055		1,016		1,422		1,502		Other	1,111		1,055		1,432		1,422
Total operating revenues	Total operating revenues	358,723		360,074		703,011		676,127		Total operating revenues	413,838		358,723		843,497		703,011

Operating Expenses:	Operating Expenses:									Operating Expenses:
Electric utility:	Electric utility:									Electric utility:
Purchased power	Purchased power	91,727		96,116		177,151		164,104		Purchased power	91,460		91,727		262,554		177,151
Fuel expense	Fuel expense	34,417		31,191		80,119		64,496		Fuel expense	31,113		34,417		120,194		80,119
Power cost adjustment	Power cost adjustment	(426)		(7,934)		(825)		(2,263)		Power cost adjustment	49,629		(426)		(1,708)		(825)
Other operations and maintenance	Other operations and maintenance	100,556		88,490		192,642		174,148		Other operations and maintenance	97,123		100,556		189,164		192,642
Energy efficiency programs	Energy efficiency programs	6,609		6,658		13,198		15,685		Energy efficiency programs	6,552		6,609		11,767		13,198
Depreciation	Depreciation	34,830		43,627		79,287		86,942		Depreciation	47,108		34,830		92,499		79,287
Other electric utility operating expenses	Other electric utility operating expenses	8,865		9,007		17,765		18,333		Other electric utility operating expenses	7,846		8,865		16,871		17,765
Total electric utility operating expenses	Total electric utility operating expenses	276,578		267,155		559,337		521,445		Total electric utility operating expenses	330,831		276,578		691,341		559,337
Other	Other	639		515		1,500		1,170		Other	713		639		1,758		1,500
Total operating expenses	Total operating expenses	277,217		267,670		560,837		522,615		Total operating expenses	331,544		277,217		693,099		560,837

Operating Income	Operating Income	81,506		92,404		142,174		153,512		Operating Income	82,294		81,506		150,398		142,174

Nonoperating (Income) Expense:	Nonoperating (Income) Expense:									Nonoperating (Income) Expense:
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(9,287)		(7,795)		(18,410)		(15,564)		Allowance for equity funds used during construction	(11,173)		(9,287)		(21,081)		(18,410)
Earnings of unconsolidated equity-method investments	Earnings of unconsolidated equity-method investments	(2,288)		(2,313)		(4,596)		(4,630)		Earnings of unconsolidated equity-method investments	(2,739)		(2,288)		(5,192)		(4,596)
Interest on long-term debt	Interest on long-term debt	21,374		21,036		42,443		42,073		Interest on long-term debt	28,579		21,374		53,547		42,443
Other interest	Other interest	3,860		3,611		7,675		7,130		Other interest	4,609		3,860		9,363		7,675
Allowance for borrowed funds used during construction	Allowance for borrowed funds used during construction	(3,481)		(3,019)		(6,865)		(6,025)		Allowance for borrowed funds used during construction	(5,161)		(3,481)		(9,389)		(6,865)
Other income, net	Other income, net	(1,551)		(460)		(3,163)		(702)		Other income, net	(8,816)		(1,551)		(16,964)		(3,163)
Total nonoperating expense, net	Total nonoperating expense, net	8,627		11,060		17,084		22,282		Total nonoperating expense, net	5,299		8,627		10,284		17,084

Income Before Income Taxes	Income Before Income Taxes	72,879		81,344		125,090		131,230		Income Before Income Taxes	76,995		72,879		140,114		125,090

Income Tax Expense	Income Tax Expense	8,291		11,070		14,317		16,156		Income Tax Expense	8,131		8,291		15,226		14,317

Net Income	Net Income	64,588		70,274		110,773		115,074		Net Income	68,864		64,588		124,888		110,773
Income attributable to noncontrolling interests	Income attributable to noncontrolling interests	(301)		(251)		(225)		(220)		Income attributable to noncontrolling interests	(290)		(301)		(216)		(225)
Net Income Attributable to IDACORP, Inc.	Net Income Attributable to IDACORP, Inc.	$	64,287	$	70,023	$	110,548	$	114,854	Net Income Attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548

Weighted Average Common Shares Outstanding - Basic	Weighted Average Common Shares Outstanding - Basic	50,668		50,609		50,650		50,588		Weighted Average Common Shares Outstanding - Basic	50,725		50,668		50,707		50,650
Weighted Average Common Shares Outstanding - Diluted	Weighted Average Common Shares Outstanding - Diluted	50,687		50,622		50,673		50,601		Weighted Average Common Shares Outstanding - Diluted	50,758		50,687		50,741		50,673
Earnings Per Share of Common Stock:	Earnings Per Share of Common Stock:									Earnings Per Share of Common Stock:
Earnings Attributable to IDACORP, Inc. - Basic	Earnings Attributable to IDACORP, Inc. - Basic	$	1.27	$	1.38	$	2.18	$	2.27	Earnings Attributable to IDACORP, Inc. - Basic	$	1.35	$	1.27	$	2.46	$	2.18
Earnings Attributable to IDACORP, Inc. - Diluted	Earnings Attributable to IDACORP, Inc. - Diluted	$	1.27	$	1.38	$	2.18	$	2.27	Earnings Attributable to IDACORP, Inc. - Diluted	$	1.35	$	1.27	$	2.46	$	2.18

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Statements of Comprehensive Income

(unaudited)


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Net Income	Net Income	$	64,588	$	70,274	$	110,773	$	115,074	Net Income	$	68,864	$	64,588	$	124,888	$	110,773
Other Comprehensive Income:	Other Comprehensive Income:									Other Comprehensive Income:

Unfunded pension liability adjustment, net of tax of $290, $290, $580, and $579, respectively		837		836		1,674		1,672
Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively										Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively	147		837		293		1,674
Total Comprehensive Income	Total Comprehensive Income	65,425		71,110		112,447		116,746		Total Comprehensive Income	69,011		65,425		125,181		112,447
Income attributable to noncontrolling interests	Income attributable to noncontrolling interests	(301)		(251)		(225)		(220)		Income attributable to noncontrolling interests	(290)		(301)		(216)		(225)
Comprehensive Income Attributable to IDACORP, Inc.	Comprehensive Income Attributable to IDACORP, Inc.	$	65,124	$	70,859	$	112,222	$	116,526	Comprehensive Income Attributable to IDACORP, Inc.	$	68,721	$	65,124	$	124,965	$	112,222

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in thousands)					(in thousands)
Assets	Assets					Assets

Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	237,886	$	215,243	Cash and cash equivalents	$	134,779	$	177,577
Short-term investments		25,000		—

Receivables:	Receivables:					Receivables:
Customer (net of allowance of $3,921 and $4,499, respectively)		90,604		78,819
Other (net of allowance of $441 and $517, respectively)		13,012		14,994
Customer (net of allowance of $3,856 and $5,034, respectively)						Customer (net of allowance of $3,856 and $5,034, respectively)	112,730		114,173
Other (net of allowance of $567 and $512, respectively)						Other (net of allowance of $567 and $512, respectively)	56,419		51,179
Income taxes receivable	Income taxes receivable	—		14,770		Income taxes receivable	—		13,734
Accrued unbilled revenues	Accrued unbilled revenues	94,757		74,843		Accrued unbilled revenues	93,000		84,862
Materials and supplies (at average cost)	Materials and supplies (at average cost)	78,715		77,552		Materials and supplies (at average cost)	121,215		92,461
Fuel stock (at average cost)	Fuel stock (at average cost)	16,023		18,045		Fuel stock (at average cost)	16,498		14,762
Prepayments	Prepayments	23,301		24,676		Prepayments	23,832		24,517
Current regulatory assets	Current regulatory assets	98,550		71,223		Current regulatory assets	174,848		80,049
Other	Other	15,496		5,708		Other	313		40,339
Total current assets	Total current assets	693,344		595,873		Total current assets	733,634		693,653
Investments	Investments	114,048		123,824		Investments	126,839		121,352
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Utility plant in service	Utility plant in service	6,680,494		6,509,316		Utility plant in service	6,984,783		6,828,467
Accumulated provision for depreciation	Accumulated provision for depreciation	(2,395,644)		(2,298,951)		Accumulated provision for depreciation	(2,544,166)		(2,465,279)
Utility plant in service - net	Utility plant in service - net	4,284,850		4,210,365		Utility plant in service - net	4,440,617		4,363,188
Construction work in progress	Construction work in progress	708,529		670,585		Construction work in progress	990,181		785,706
Utility plant held for future use	Utility plant held for future use	4,089		4,511		Utility plant held for future use	8,860		7,130
Other property, net of accumulated depreciation	Other property, net of accumulated depreciation	16,983		16,361		Other property, net of accumulated depreciation	16,466		16,946
Property, plant and equipment - net	Property, plant and equipment - net	5,014,451		4,901,822		Property, plant and equipment - net	5,456,124		5,172,970
Other Assets:	Other Assets:					Other Assets:
Company-owned life insurance	Company-owned life insurance	70,180		67,343		Company-owned life insurance	77,999		73,944
Regulatory assets	Regulatory assets	1,496,817		1,462,431		Regulatory assets	1,381,398		1,421,912

Other	Other	63,256		59,222		Other	63,074		59,427
Total other assets	Total other assets	1,630,253		1,588,996		Total other assets	1,522,471		1,555,283
Total	Total	$	7,452,096	$	7,210,515	Total	$	7,839,068	$	7,543,258

The accompanying notes are an integral part of these statements.

Table of Contents

IDACORP, Inc.

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in thousands)					(in thousands)
Liabilities and Equity	Liabilities and Equity					Liabilities and Equity

Current Liabilities:	Current Liabilities:					Current Liabilities:
Current maturities of long-term debt		$	75,000	$	—

Accounts payable	Accounts payable	152,569		145,980		Accounts payable	$	223,653	$	292,719
Taxes accrued	Taxes accrued	30,712		14,229		Taxes accrued	30,640		8,565
Interest accrued	Interest accrued	23,924		23,959		Interest accrued	32,026		24,060
Accrued compensation	Accrued compensation	49,236		55,666		Accrued compensation	47,948		59,265
Current regulatory liabilities	Current regulatory liabilities	20,101		11,239		Current regulatory liabilities	6,405		63,957
Advances from customers	Advances from customers	67,400		43,472		Advances from customers	91,262		72,222
Other	Other	30,038		31,079		Other	36,404		27,777
Total current liabilities	Total current liabilities	448,980		325,624		Total current liabilities	468,338		548,565
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes	Deferred income taxes	828,758		842,375		Deferred income taxes	861,478		873,916
Regulatory liabilities	Regulatory liabilities	794,753		781,695		Regulatory liabilities	803,547		796,644
Pension and other postretirement benefits	Pension and other postretirement benefits	521,963		521,462		Pension and other postretirement benefits	238,777		238,037
Other	Other	68,114		63,485		Other	123,221		77,336
Total other liabilities	Total other liabilities	2,213,588		2,209,017		Total other liabilities	2,027,023		1,985,933
Long-Term Debt	Long-Term Debt	2,075,698		2,000,640		Long-Term Debt	2,482,352		2,194,145
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies
Equity:	Equity:					Equity:
IDACORP, Inc. shareholders’ equity:	IDACORP, Inc. shareholders’ equity:					IDACORP, Inc. shareholders’ equity:
Common stock, no par value (120,000 shares authorized; 50,560 and 50,516 shares issued, respectively)		877,362		874,896
Common stock, no par value (120,000 shares authorized; 50,615 and 50,562 shares issued, respectively)						Common stock, no par value (120,000 shares authorized; 50,615 and 50,562 shares issued, respectively)	884,309		882,189
Retained earnings	Retained earnings	1,867,811		1,833,580		Retained earnings	1,982,083		1,937,972
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(38,366)		(40,040)		Accumulated other comprehensive loss	(12,629)		(12,922)

Total IDACORP, Inc. shareholders’ equity	Total IDACORP, Inc. shareholders’ equity	2,706,807		2,668,436		Total IDACORP, Inc. shareholders’ equity	2,853,763		2,807,239
Noncontrolling interests	Noncontrolling interests	7,023		6,798		Noncontrolling interests	7,592		7,376
Total equity	Total equity	2,713,830		2,675,234		Total equity	2,861,355		2,814,615
Total	Total	$	7,452,096	$	7,210,515	Total	$	7,839,068	$	7,543,258

The accompanying notes are an integral part of these statements.	The accompanying notes are an integral part of these statements.					The accompanying notes are an integral part of these statements.

Table of Contents

IDACORP, Inc.

Condensed Consolidated Statements of Cash Flows

(unaudited)


		Six months ended June 30,					Six months ended June 30,
		2022		2021			2023		2022
		(in thousands)					(in thousands)
Operating Activities:	Operating Activities:					Operating Activities:
Net income	Net income	$	110,773	$	115,074	Net income	$	124,888	$	110,773
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	81,351		88,889		Depreciation and amortization	94,677		81,351
Deferred income taxes and investment tax credits	Deferred income taxes and investment tax credits	(16,953)		(6,169)		Deferred income taxes and investment tax credits	(15,209)		(16,953)
Changes in regulatory assets and liabilities	Changes in regulatory assets and liabilities	8,658		9,311		Changes in regulatory assets and liabilities	(8,255)		8,658
Pension and postretirement benefit plan expense	Pension and postretirement benefit plan expense	14,484		14,534		Pension and postretirement benefit plan expense	13,626		14,484
Contributions to pension and postretirement benefit plans	Contributions to pension and postretirement benefit plans	(12,122)		(11,957)		Contributions to pension and postretirement benefit plans	(13,818)		(12,122)
Earnings of equity-method investments	Earnings of equity-method investments	(4,596)		(4,630)		Earnings of equity-method investments	(5,192)		(4,596)
Distributions from equity-method investments	Distributions from equity-method investments	4,265		4,100		Distributions from equity-method investments	—		4,265
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(18,410)		(15,564)		Allowance for equity funds used during construction	(21,081)		(18,410)
Other non-cash adjustments to net income, net	Other non-cash adjustments to net income, net	5,953		4,428		Other non-cash adjustments to net income, net	3,550		5,953
Change in:	Change in:					Change in:
Receivables		(13,045)		(15,241)
Accounts payable and other accrued liabilities		(23,439)		2,620
Accounts receivable and unbilled revenues						Accounts receivable and unbilled revenues	(28,539)		(31,690)
Prepayments						Prepayments	(2,762)		743
Materials, supplies, and fuel stock						Materials, supplies, and fuel stock	(30,490)		858
Accounts and wages payable						Accounts and wages payable	(138,469)		(23,439)
Taxes accrued/receivable	Taxes accrued/receivable	31,253		25,728		Taxes accrued/receivable	35,809		31,253
Other current assets		(17,044)		(48,206)
Other current liabilities		7,882		5,658
Other assets		(7,590)		(3,285)
Other liabilities		4,535		1,905
Other assets and liabilities						Other assets and liabilities	(1,956)		4,827
Net cash provided by operating activities	Net cash provided by operating activities	155,955		167,195		Net cash provided by operating activities	6,779		155,955
Investing Activities:	Investing Activities:					Investing Activities:
Additions to property, plant and equipment	Additions to property, plant and equipment	(194,094)		(128,265)		Additions to property, plant and equipment	(274,167)		(194,094)
Payments received from transmission project joint funding partners	Payments received from transmission project joint funding partners	5,531		2,253		Payments received from transmission project joint funding partners	8,953		5,531

Investments in affordable housing and other real estate tax credits projects	Investments in affordable housing and other real estate tax credits projects	(2,665)		(10,164)		Investments in affordable housing and other real estate tax credits projects	135		(2,665)

Investments in unconsolidated affiliates						Investments in unconsolidated affiliates	(4,900)		—
Distributions from equity-method investments, return of investment	Distributions from equity-method investments, return of investment	10,335		—		Distributions from equity-method investments, return of investment	—		10,335
Purchases of equity securities	Purchases of equity securities	(27,942)		(392)		Purchases of equity securities	(1,926)		(27,942)
Purchases of held-to-maturity securities	Purchases of held-to-maturity securities	(29,692)		—		Purchases of held-to-maturity securities	(733)		(29,692)
Proceeds from the sale of equity securities	Proceeds from the sale of equity securities	52,833		3,197		Proceeds from the sale of equity securities	4,401		52,833
Purchases of short-term investments	Purchases of short-term investments	(25,000)		(25,000)		Purchases of short-term investments	—		(25,000)
Maturities of short-term investments		—		50,000

Other	Other	6,767		1,347		Other	4,438		6,767
Net cash used in investing activities	Net cash used in investing activities	(203,927)		(107,024)		Net cash used in investing activities	(263,799)		(203,927)
Financing Activities:	Financing Activities:					Financing Activities:
Issuance of long-term debt	Issuance of long-term debt	150,000		—		Issuance of long-term debt	522,000		150,000

Discount on issuance of long-term debt						Discount on issuance of long-term debt	(3,772)		—
Retirement of long-term debt						Retirement of long-term debt	(225,000)		—
Dividends on common stock	Dividends on common stock	(76,339)		(72,285)		Dividends on common stock	(80,538)		(76,339)

Tax withholdings on net settlements of share-based awards	Tax withholdings on net settlements of share-based awards	(2,958)		(3,026)		Tax withholdings on net settlements of share-based awards	(3,255)		(2,958)

Debt issuance costs and other		(88)		(11)
Net cash provided by (used in) financing activities		70,615		(75,322)
Net increase (decrease) in cash and cash equivalents		22,643		(15,151)
Other						Other	4,787		(88)
Net cash provided by financing activities						Net cash provided by financing activities	214,222		70,615
Net (decrease) increase in cash and cash equivalents						Net (decrease) increase in cash and cash equivalents	(42,798)		22,643
Cash and cash equivalents at beginning of the period	Cash and cash equivalents at beginning of the period	215,243		275,116		Cash and cash equivalents at beginning of the period	177,577		215,243
Cash and cash equivalents at end of the period	Cash and cash equivalents at end of the period	$	237,886	$	259,965	Cash and cash equivalents at end of the period	$	134,779	$	237,886
Supplemental Disclosure of Cash Flow Information:	Supplemental Disclosure of Cash Flow Information:					Supplemental Disclosure of Cash Flow Information:
Cash paid during the period for:	Cash paid during the period for:					Cash paid during the period for:
Income taxes	Income taxes	$	6,265	$	2,880	Income taxes	$	—	$	6,265
Interest (net of amount capitalized)	Interest (net of amount capitalized)	$	41,657	$	41,626	Interest (net of amount capitalized)	$	43,927	$	41,657
Non-cash investing activities:	Non-cash investing activities:					Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	Additions to property, plant and equipment in accounts payable	$	70,063	$	30,984	Additions to property, plant and equipment in accounts payable	$	137,717	$	70,063

The accompanying notes are an integral part of these statements.

Table of Contents

IDACORP, Inc.

Condensed Consolidated Statements of Equity

(unaudited)


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
Common Stock	Common Stock									Common Stock
Balance at beginning of period	Balance at beginning of period	$	875,067	$	868,944	$	874,896	$	869,235	Balance at beginning of period	$	882,104	$	875,067	$	882,189	$	874,896
Share-based compensation expense	Share-based compensation expense	2,262		2,140		5,364		4,850		Share-based compensation expense	2,167		2,262		5,304		5,364
Tax withholdings on net settlements of share-based awards	Tax withholdings on net settlements of share-based awards	—		—		(2,958)		(3,026)		Tax withholdings on net settlements of share-based awards	—		—		(3,255)		(2,958)

Other	Other	33		27		60		52		Other	38		33		71		60
Balance at end of period	Balance at end of period	877,362		871,111		877,362		871,111		Balance at end of period	884,309		877,362		884,309		877,362
Retained Earnings	Retained Earnings									Retained Earnings
Balance at beginning of period	Balance at beginning of period	1,841,644		1,742,994		1,833,580		1,734,103		Balance at beginning of period	1,953,727		1,841,644		1,937,972		1,833,580
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	64,287		70,023		110,548		114,854		Net income attributable to IDACORP, Inc.	68,574		64,287		124,672		110,548
Common stock dividends ($0.75, $0.71, $1.50, and $1.42 per share, respectively)		(38,120)		(36,031)		(76,317)		(71,971)
Common stock dividends ($0.79, $0.75, $1.58, and $1.50 per share, respectively)										Common stock dividends ($0.79, $0.75, $1.58, and $1.50 per share, respectively)	(40,218)		(38,120)		(80,561)		(76,317)
Balance at end of period	Balance at end of period	1,867,811		1,776,986		1,867,811		1,776,986		Balance at end of period	1,982,083		1,867,811		1,982,083		1,867,811
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss									Accumulated Other Comprehensive Loss
Balance at beginning of period	Balance at beginning of period	(39,203)		(42,522)		(40,040)		(43,358)		Balance at beginning of period	(12,776)		(39,203)		(12,922)		(40,040)
Unfunded pension liability adjustment (net of tax)	Unfunded pension liability adjustment (net of tax)	837		836		1,674		1,672		Unfunded pension liability adjustment (net of tax)	147		837		293		1,674
Balance at end of period	Balance at end of period	(38,366)		(41,686)		(38,366)		(41,686)		Balance at end of period	(12,629)		(38,366)		(12,629)		(38,366)

Total IDACORP, Inc. shareholders’ equity at end of period	Total IDACORP, Inc. shareholders’ equity at end of period	2,706,807		2,606,411		2,706,807		2,606,411		Total IDACORP, Inc. shareholders’ equity at end of period	2,853,763		2,706,807		2,853,763		2,706,807
Noncontrolling Interests	Noncontrolling Interests									Noncontrolling Interests
Balance at beginning of period	Balance at beginning of period	6,722		6,445		6,798		6,476		Balance at beginning of period	7,302		6,722		7,376		6,798
Net loss attributable to noncontrolling interests		301		251		225		220
Net income attributable to noncontrolling interests										Net income attributable to noncontrolling interests	290		301		216		225
Balance at end of period	Balance at end of period	7,023		6,696		7,023		6,696		Balance at end of period	7,592		7,023		7,592		7,023
Total equity at end of period	Total equity at end of period	$	2,713,830	$	2,613,107	$	2,713,830	$	2,613,107	Total equity at end of period	$	2,861,355	$	2,713,830	$	2,861,355	$	2,713,830

The accompanying notes are an integral part of these statements.

Table of Contents

Idaho Power Company

Condensed Consolidated Statements of Income

(unaudited)


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Operating Revenues	Operating Revenues	$	357,668	$	359,058	$	701,589	$	674,625	Operating Revenues	$	412,727	$	357,668	$	842,065	$	701,589

Operating Expenses:	Operating Expenses:									Operating Expenses:
Operation:	Operation:									Operation:
Purchased power	Purchased power	91,727		96,116		177,151		164,104		Purchased power	91,460		91,727		262,554		177,151
Fuel expense	Fuel expense	34,417		31,191		80,119		64,496		Fuel expense	31,113		34,417		120,194		80,119
Power cost adjustment	Power cost adjustment	(426)		(7,934)		(825)		(2,263)		Power cost adjustment	49,629		(426)		(1,708)		(825)
Other operations and maintenance	Other operations and maintenance	100,556		88,490		192,642		174,148		Other operations and maintenance	97,123		100,556		189,164		192,642
Energy efficiency programs	Energy efficiency programs	6,609		6,658		13,198		15,685		Energy efficiency programs	6,552		6,609		11,767		13,198
Depreciation	Depreciation	34,830		43,627		79,287		86,942		Depreciation	47,108		34,830		92,499		79,287
Other operating expenses	Other operating expenses	8,865		9,007		17,765		18,333		Other operating expenses	7,846		8,865		16,871		17,765
Total operating expenses	Total operating expenses	276,578		267,155		559,337		521,445		Total operating expenses	330,831		276,578		691,341		559,337

Operating Income	Operating Income	81,090		91,903		142,252		153,180		Operating Income	81,896		81,090		150,724		142,252

Nonoperating (Income) Expense:	Nonoperating (Income) Expense:									Nonoperating (Income) Expense:
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(9,287)		(7,795)		(18,410)		(15,564)		Allowance for equity funds used during construction	(11,173)		(9,287)		(21,081)		(18,410)
Earnings of unconsolidated equity-method investments	Earnings of unconsolidated equity-method investments	(1,784)		(1,743)		(4,265)		(4,293)		Earnings of unconsolidated equity-method investments	(1,923)		(1,784)		(4,395)		(4,265)
Interest on long-term debt	Interest on long-term debt	21,374		21,036		42,443		42,073		Interest on long-term debt	28,579		21,374		53,547		42,443
Other interest	Other interest	3,854		3,606		7,665		7,120		Other interest	4,529		3,854		9,203		7,665
Allowance for borrowed funds used during construction	Allowance for borrowed funds used during construction	(3,481)		(3,019)		(6,865)		(6,025)		Allowance for borrowed funds used during construction	(5,161)		(3,481)		(9,389)		(6,865)
Other income, net	Other income, net	(1,337)		(423)		(2,978)		(613)		Other income, net	(8,319)		(1,337)		(15,845)		(2,978)
Total nonoperating expense, net	Total nonoperating expense, net	9,339		11,662		17,590		22,698		Total nonoperating expense, net	6,532		9,339		12,040		17,590

Income Before Income Taxes	Income Before Income Taxes	71,751		80,241		124,662		130,482		Income Before Income Taxes	75,364		71,751		138,684		124,662

Income Tax Expense	Income Tax Expense	9,316		11,419		16,013		17,291		Income Tax Expense	8,284		9,316		15,894		16,013

Net Income	Net Income	$	62,435	$	68,822	$	108,649	$	113,191	Net Income	$	67,080	$	62,435	$	122,790	$	108,649

The accompanying notes are an integral part of these statements.

Table of Contents

Idaho Power Company

Condensed Consolidated Statements of Comprehensive Income

(unaudited)


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Net Income	Net Income	$	62,435	$	68,822	$	108,649	$	113,191	Net Income	$	67,080	$	62,435	$	122,790	$	108,649
Other Comprehensive Income:	Other Comprehensive Income:									Other Comprehensive Income:

Unfunded pension liability adjustment, net of tax of $290, $290, $580, and $579, respectively		837		836		1,674		1,672
Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively										Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively	147		837		293		1,674
Total Comprehensive Income	Total Comprehensive Income	$	63,272	$	69,658	$	110,323	$	114,863	Total Comprehensive Income	$	67,227	$	63,272	$	123,083	$	110,323

The accompanying notes are an integral part of these statements.

Table of Contents

Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in thousands)					(in thousands)
Assets	Assets					Assets

Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	103,607	$	60,075	Cash and cash equivalents	$	104,455	$	108,933
Receivables:	Receivables:					Receivables:
Customer (net of allowance of $3,921 and $4,499, respectively)		90,604		78,819
Other (net of allowance of $441 and $517, respectively)		12,702		14,134
Customer (net of allowance of $3,856 and $5,034, respectively)						Customer (net of allowance of $3,856 and $5,034, respectively)	112,730		114,173
Other (net of allowance of $567 and $512, respectively)						Other (net of allowance of $567 and $512, respectively)	56,167		50,754
Income taxes receivable	Income taxes receivable	—		15,328		Income taxes receivable	—		13,108
Accrued unbilled revenues	Accrued unbilled revenues	94,757		74,843		Accrued unbilled revenues	93,000		84,862
Materials and supplies (at average cost)	Materials and supplies (at average cost)	78,715		77,552		Materials and supplies (at average cost)	121,215		92,461
Fuel stock (at average cost)	Fuel stock (at average cost)	16,023		18,045		Fuel stock (at average cost)	16,498		14,762
Prepayments	Prepayments	23,172		24,558		Prepayments	23,703		24,396

Current regulatory assets	Current regulatory assets	98,550		71,223		Current regulatory assets	174,848		80,049
Other	Other	15,496		5,708		Other	313		40,339
Total current assets	Total current assets	533,626		440,285		Total current assets	702,929		623,837
Investments	Investments	69,058		77,108		Investments	86,096		78,791
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Plant in service	Plant in service	6,680,494		6,509,316		Plant in service	6,984,783		6,828,467
Accumulated provision for depreciation	Accumulated provision for depreciation	(2,395,644)		(2,298,951)		Accumulated provision for depreciation	(2,544,166)		(2,465,279)
Plant in service - net	Plant in service - net	4,284,850		4,210,365		Plant in service - net	4,440,617		4,363,188
Construction work in progress	Construction work in progress	708,529		670,585		Construction work in progress	990,181		785,706
Plant held for future use	Plant held for future use	4,089		4,511		Plant held for future use	8,860		7,130
Other property	Other property	4,357		3,647		Other property	4,316		4,558
Property, plant and equipment, net	Property, plant and equipment, net	5,001,825		4,889,108		Property, plant and equipment, net	5,443,974		5,160,582
Other Assets:	Other Assets:					Other Assets:
Company-owned life insurance	Company-owned life insurance	70,180		67,343		Company-owned life insurance	77,999		73,944
Regulatory assets	Regulatory assets	1,496,817		1,462,431		Regulatory assets	1,381,398		1,421,912
Other	Other	58,156		54,564		Other	54,721		52,038
Total other assets	Total other assets	1,625,153		1,584,338		Total other assets	1,514,118		1,547,894
Total	Total	$	7,229,662	$	6,990,839	Total	$	7,747,117	$	7,411,104

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
		(in thousands)					(in thousands)
Liabilities and Equity	Liabilities and Equity					Liabilities and Equity

Current Liabilities:	Current Liabilities:					Current Liabilities:
Current maturities of long-term debt		$	75,000	$	—

Accounts payable	Accounts payable	152,475		145,871		Accounts payable	$	222,977	$	292,616
Accounts payable to affiliates	Accounts payable to affiliates	2,699		2,159		Accounts payable to affiliates	59,126		56,338
Taxes accrued	Taxes accrued	29,086		14,316		Taxes accrued	32,808		9,101
Interest accrued	Interest accrued	23,924		23,959		Interest accrued	32,026		24,060

Accrued compensation	Accrued compensation	48,948		55,491		Accrued compensation	47,728		58,959
Current regulatory liabilities	Current regulatory liabilities	20,101		11,239		Current regulatory liabilities	6,405		63,957
Advances from customers	Advances from customers	67,400		43,472		Advances from customers	91,262		72,222
Other	Other	20,552		19,117		Other	34,854		26,199
Total current liabilities	Total current liabilities	440,185		315,624		Total current liabilities	527,186		603,452
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes	Deferred income taxes	831,492		844,871		Deferred income taxes	858,421		870,692
Regulatory liabilities	Regulatory liabilities	794,753		781,695		Regulatory liabilities	803,547		796,644
Pension and other postretirement benefits	Pension and other postretirement benefits	521,963		521,462		Pension and other postretirement benefits	238,777		238,037
Other	Other	67,264		62,245		Other	122,666		76,471
Total other liabilities	Total other liabilities	2,215,472		2,210,273		Total other liabilities	2,023,411		1,981,844
Long-Term Debt	Long-Term Debt	2,075,698		2,000,640		Long-Term Debt	2,482,352		2,194,145
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies
Equity:	Equity:					Equity:
Common stock, $2.50 par value (50,000 shares authorized; 39,151 shares outstanding)	Common stock, $2.50 par value (50,000 shares authorized; 39,151 shares outstanding)	97,877		97,877		Common stock, $2.50 par value (50,000 shares authorized; 39,151 shares outstanding)	97,877		97,877
Premium on capital stock	Premium on capital stock	712,258		712,258		Premium on capital stock	712,258		712,258
Capital stock expense	Capital stock expense	(2,097)		(2,097)		Capital stock expense	(2,097)		(2,097)
Retained earnings	Retained earnings	1,728,635		1,696,304		Retained earnings	1,918,759		1,836,547
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(38,366)		(40,040)		Accumulated other comprehensive loss	(12,629)		(12,922)
Total equity	Total equity	2,498,307		2,464,302		Total equity	2,714,168		2,631,663
Total	Total	$	7,229,662	$	6,990,839	Total	$	7,747,117	$	7,411,104

The accompanying notes are an integral part of these statements.	The accompanying notes are an integral part of these statements.					The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Statements of Cash Flows

(unaudited)


		Six months ended June 30,					Six months ended June 30,
		2022		2021			2023		2022
		(in thousands)					(in thousands)
Operating Activities:	Operating Activities:					Operating Activities:
Net income	Net income	$	108,649	$	113,191	Net income	$	122,790	$	108,649
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	81,053		88,593		Depreciation and amortization	94,382		81,053
Deferred income taxes and investment tax credits	Deferred income taxes and investment tax credits	(19,471)		(5,393)		Deferred income taxes and investment tax credits	(18,097)		(19,471)
Changes in regulatory assets and liabilities	Changes in regulatory assets and liabilities	8,658		9,311		Changes in regulatory assets and liabilities	(8,255)		8,658
Pension and postretirement benefit plan expense	Pension and postretirement benefit plan expense	14,484		14,534		Pension and postretirement benefit plan expense	13,626		14,484
Contributions to pension and postretirement benefit plans	Contributions to pension and postretirement benefit plans	(12,122)		(11,957)		Contributions to pension and postretirement benefit plans	(13,818)		(12,122)
Earnings of equity-method investments	Earnings of equity-method investments	(4,265)		(4,293)		Earnings of equity-method investments	(4,395)		(4,265)
Distributions from equity-method investments	Distributions from equity-method investments	4,265		4,100		Distributions from equity-method investments	—		4,265
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(18,410)		(15,564)		Allowance for equity funds used during construction	(21,081)		(18,410)
Other non-cash adjustments to net income, net	Other non-cash adjustments to net income, net	464		(422)		Other non-cash adjustments to net income, net	(1,665)		464
Change in:	Change in:					Change in:
Receivables		(13,064)		(14,535)
Accounts payable		(23,425)		2,616
Accounts receivable and unbilled revenues						Accounts receivable and unbilled revenues	(28,436)		(31,709)
Prepayments						Prepayments	(2,754)		754
Materials, supplies, and fuel stock						Materials, supplies, and fuel stock	(30,490)		858
Accounts and wages payable						Accounts and wages payable	(136,183)		(23,426)
Taxes accrued/receivable	Taxes accrued/receivable	30,097		18,908		Taxes accrued/receivable	36,814		30,097
Other current assets		(17,033)		(48,203)
Other current liabilities		7,795		5,728
Other assets		(7,613)		(3,307)
Other liabilities		4,630		1,999
Other assets and liabilities						Other assets and liabilities	(1,837)		4,813
Net cash provided by operating activities	Net cash provided by operating activities	144,692		155,306		Net cash provided by operating activities	601		144,692
Investing Activities:	Investing Activities:					Investing Activities:
Additions to utility plant		(193,940)		(128,264)
Additions to property, plant and equipment						Additions to property, plant and equipment	(274,162)		(193,940)

Payments received from transmission project joint funding partners	Payments received from transmission project joint funding partners	5,531		2,253		Payments received from transmission project joint funding partners	8,953		5,531

Distributions from equity-method investments, return of investment	Distributions from equity-method investments, return of investment	10,335		—		Distributions from equity-method investments, return of investment	—		10,335

Investments in unconsolidated affiliates						Investments in unconsolidated affiliates	(4,900)		—
Purchases of equity securities	Purchases of equity securities	(27,118)		(392)		Purchases of equity securities	(1,576)		(27,118)
Purchases of held-to-maturity securities	Purchases of held-to-maturity securities	(29,692)		—		Purchases of held-to-maturity securities	(733)		(29,692)
Proceeds from the sale of equity securities	Proceeds from the sale of equity securities	52,833		3,197		Proceeds from the sale of equity securities	4,401		52,833

Other	Other	7,282		1,347		Other	5,473		7,282
Net cash used in investing activities	Net cash used in investing activities	(174,769)		(121,859)		Net cash used in investing activities	(262,544)		(174,769)
Financing Activities:	Financing Activities:					Financing Activities:
Issuance of long-term debt	Issuance of long-term debt	150,000		—		Issuance of long-term debt	522,000		150,000

Discount on issuance of long-term debt						Discount on issuance of long-term debt	(3,772)		—
Retirement of long-term debt						Retirement of long-term debt	(225,000)		—
Dividends on common stock	Dividends on common stock	(76,318)		(71,972)		Dividends on common stock	(40,625)		(76,318)

Debt issuance costs and other		(73)		(9)
Net cash provided by (used in) financing activities		73,609		(71,981)
Net increase (decrease) in cash and cash equivalents		43,532		(38,534)
Other						Other	4,862		(73)
Net cash provided by financing activities						Net cash provided by financing activities	257,465		73,609
Net (decrease) increase in cash and cash equivalents						Net (decrease) increase in cash and cash equivalents	(4,478)		43,532
Cash and cash equivalents at beginning of the period	Cash and cash equivalents at beginning of the period	60,075		165,604		Cash and cash equivalents at beginning of the period	108,933		60,075
Cash and cash equivalents at end of the period	Cash and cash equivalents at end of the period	$	103,607	$	127,070	Cash and cash equivalents at end of the period	$	104,455	$	103,607
Supplemental Disclosure of Cash Flow Information:	Supplemental Disclosure of Cash Flow Information:					Supplemental Disclosure of Cash Flow Information:
Cash paid to IDACORP related to income taxes	Cash paid to IDACORP related to income taxes	$	10,645	$	10,046	Cash paid to IDACORP related to income taxes	$	—	$	10,645
Cash paid for interest (net of amount capitalized)	Cash paid for interest (net of amount capitalized)	$	41,647	$	41,616	Cash paid for interest (net of amount capitalized)	$	43,767	$	41,647
Non-cash investing activities:	Non-cash investing activities:					Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	Additions to property, plant and equipment in accounts payable	$	70,063	$	30,984	Additions to property, plant and equipment in accounts payable	$	137,717	$	70,063

The accompanying notes are an integral part of these statements.

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IDACORP, INC. AND IDAHO POWER COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

This Quarterly Report on Form 10-Q is a combined report of IDACORP, Inc. (IDACORP) and Idaho Power Company (Idaho Power). Therefore, these Notes to the Condensed Consolidated Financial Statements apply to both IDACORP and Idaho Power. However, Idaho Power makes no representation as to the information relating to IDACORP’s other operations.

Nature of Business

IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sale, and purchase of electric energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. Idaho Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the Federal Energy Regulatory Commission. Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger ~~generating~~power plant (Jim Bridger plant) owned in part by Idaho Power.

IDACORP’s ~~significant~~ other notable wholly-owned subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate tax credit investments, and Ida-West Energy Company (Ida-West), an operator of small hydropower generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA).

Regulation of Utility Operations

As a regulated utility, many of Idaho Power's fundamental business decisions are subject to the approval of governmental agencies, including the prices that Idaho Power is authorized to charge for its electric service. These approvals are a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition.

IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power. The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and revenues in a different period than when an unregulated enterprise would record such expenses and revenues. In these instances, the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet. Regulatory assets represent incurred costs that have been deferred because it is probable they will be recovered from customers through future rates. Regulatory liabilities represent obligations to make refunds to customers for previous collections, or represent amounts collected in advance of incurring an expense. The effects of applying these regulatory accounting principles to Idaho Power's operations are discussed in more detail in Note 3 - "Regulatory Matters."

Financial Statements

In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's condensed consolidated ~~financial position~~balance sheets as of June 30, ~~2022,~~2023, condensed consolidated ~~results~~statements of ~~operations~~income for the three months and six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, and condensed consolidated cash flows for the six months ended June 30, ~~2022~~2023 and ~~2021.~~2022. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or note disclosures concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP’s and Idaho Power’s Annual Report on Form 10-K for the year ended December 31, ~~2021 (2021~~2022 (2022 Annual Report). The ~~results~~statements of ~~operations~~income for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective ~~financial condition~~balance sheets and ~~results~~statements of ~~operations~~income during the period in which such change occurred.

Management Estimates

Management makes estimates and assumptions when preparing financial statements in conformity with accounting principles generally accepted ~~accounting principles~~ in the United States of America (GAAP). These estimates and assumptions include, among others, those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and ~~liabilities at the~~

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liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments with respect to, among other things, future economic factors that are difficult to predict and are beyond management's control. Accordingly, actual results could differ from those estimates.

New and Recently Adopted Accounting Pronouncements

There have been no recently issued accounting pronouncements that have had or are expected to have a material impact on IDACORP's or Idaho Power's condensed consolidated financial statements.

2. INCOME TAXES

In accordance with interim reporting requirements, IDACORP and Idaho Power use an estimated annual effective tax rate for computing their provisions for income taxes. An estimate of annual income tax expense (or benefit) is made each interim period using estimates for annual pre-tax income, income tax adjustments, and tax credits. The estimated annual effective tax rates do not include discrete events such as tax law changes, examination settlements, accounting method changes, or adjustments to tax expense or benefits attributable to prior years. Discrete events are recorded in the interim period in which they occur or become known. The estimated annual effective tax rate is applied to year-to-date pre-tax income to determine income tax expense (or benefit) for the interim period consistent with the annual estimate. In subsequent interim periods, income tax expense (or benefit) for the period is computed as the difference between the year-to-date amount reported for the previous interim period and the current period's year-to-date amount.

Income Tax Expense

The following table provides a summary of income tax expense for the six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands):


		IDACORP						Idaho Power							IDACORP						Idaho Power
		2022			2021			2022			2021				2023			2022			2023			2022
Income tax at statutory rates (federal and state)	Income tax at statutory rates (federal and state)	$	32,140		$	33,722		$	32,088		$	33,586		Income tax at statutory rates (federal and state)	$	36,010		$	32,140		$	35,697		$	32,088

Additional accumulated deferred investment tax credits (ADITC) amortization														Additional accumulated deferred investment tax credits (ADITC) amortization	(7,500)			—			(7,500)			—

Excess deferred income tax reversal	Excess deferred income tax reversal	(5,703)			(3,213)			(5,703)			(3,213)			Excess deferred income tax reversal	(5,342)			(5,703)			(5,342)			(5,703)

Other(1)	Other(1)	(12,120)			(14,353)			(10,372)			(13,082)			Other(1)	(7,942)			(12,120)			(6,961)			(10,372)
Income tax expense	Income tax expense	$	14,317		$	16,156		$	16,013		$	17,291		Income tax expense	$	15,226		$	14,317		$	15,894		$	16,013
Effective tax rate	Effective tax rate	11.5		%	12.3		%	12.8		%	13.3		%	Effective tax rate	10.9		%	11.5		%	11.5		%	12.8		%

(1) "Other" is primarily comprised of the net tax effect of Idaho Power's regulatory flow-through tax adjustments.

3. REGULATORY MATTERS

Included below is a summary of Idaho Power's most recent general rate cases and base rate changes, as well as other recent or pending notable regulatory matters and proceedings.

Idaho and Oregon General Rate Cases

Idaho Power's current base rates result from the Idaho Public Utilities Commission (IPUC) and Public Utility Commission of Oregon (OPUC) orders described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the ~~2021~~2022 Annual Report.

On June 1, 2023, Idaho Power filed a general rate case with the IPUC. The filing is based on a 2023 test year and requests approximately $111 million in additional Idaho jurisdiction annual revenues, which is net of a corresponding proposed power cost adjustment (PCA) decrease of $173.4 million and a reduction to annual energy efficiency rider collection of $3.5 million. If approved, this request would result in an 8.61 percent overall average net base rate increase for Idaho Power's Idaho customers. The filing requests, among other items, a 10.4 percent authorized rate of return on equity and an approximate $3.9 billion Idaho retail rate base. The $3.9 billion of rate base excludes rate base associated with Idaho Power's jointly-owned coal facilities, the costs of which are recovered under separate rate mechanisms. In its application, Idaho Power proposed a capitalization structure of 49 percent long-term debt and 51 percent common stock equity. Idaho Power included an average cost of debt of 4.895 percent, and an overall cost of capital of 7.702 percent.

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In addition, Idaho Power's filing requests approval or authorization of, among other items:

•Modifications to the Idaho-jurisdiction power cost adjustment (PCA) necessary to support the transfer of certain base level net power supply costs from the PCA to base rates;

•Modifications to the energy efficiency rider to support the transfer of energy efficiency labor-related cost collection from the annual energy efficiency rider into base rates;

•Modifications to the fixed cost adjustment (FCA) mechanism to support Idaho Power's proposed rate designs;

•Continued deferral of incremental vegetation management and insurance costs in 2024 and beyond as measured from a new base level of costs established in the general rate case;

•An annual $18 million increase in collection of Idaho Power’s regulatory asset associated with its defined benefit pension plan contributions;

•A rate increase mitigation measure, in lieu of increasing base rates, to (1) move an estimated $45 million of investment tax credits, including from certain battery storage projects, to the existing ADITC and revenue sharing mechanism described in more detail below, and (2) increase the existing $25 million maximum allowed annual additional accelerated ADITC amortization amount under the mechanism by a dollar amount of investment tax credits equal to the actual revenue requirement of those battery storage projects in any applicable year;

•Deferral and amortization of annual differences between certain periodic maintenance costs at Idaho Power's natural gas-fired power plants; and

•A proposed residential price modernization plan.

As of the date of this report, Idaho Power is unable to predict the outcome of the general rate case. Idaho Power anticipates that new rates, if approved by the IPUC, would become effective on or after January 1, 2024.

Idaho Settlement Stipulations

A May 2018 Idaho settlement stipulation related to tax reform (May 2018 Idaho Tax Reform Settlement Stipulation) is described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the ~~2021~~2022 Annual Report and includes provisions for the accelerated amortization of ~~accumulated deferred investment tax credits (ADITC)~~ADITC to help achieve a minimum 9.4 percent Idaho-jurisdiction return on year-end equity (Idaho ROE). In addition, under the May 2018 Idaho Tax Reform Settlement Stipulation, the Idaho ROE at which Idaho Power would begin amortizing additional ADITC would revert back to 95 percent of the authorized return on equity in the next general rate case. The settlement stipulation also provides for the potential sharing between Idaho Power and Idaho customers of Idaho-jurisdictional earnings in excess of a 10.0 percent of Idaho ~~ROE.~~ROE, which would adjust to the authorized return on equity in the next general rate case currently pending before the IPUC.

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Based on its estimate of full-year ~~2022~~2023 Idaho ROE, in the ~~second quarter of 2022,~~three and six months ended June 30, 2023, Idaho Power recorded no$3.8 million and $7.5 million, respectively, for additional ADITC amortization ~~or provision against current revenues for sharing earnings with customers~~ under the May 2018 Idaho Tax Reform Settlement Stipulation. The additional ADITC amortization was recorded in income tax expense on Idaho Power's condensed consolidated statements of income. Accordingly, at June 30, ~~2022, the full $45~~2023, $37.5 million of additional ADITC remains available for future use. Idaho Power ~~also~~ recorded no additional ADITC amortization or provision against revenues for sharing of earnings with customers during ~~the second quarter of 2021, based on its then-current estimate of full-year 2021 Idaho ROE.~~2022.

Power Cost Adjustment Mechanisms

In both its Idaho and Oregon jurisdictions, Idaho Power's power cost adjustment mechanisms address the volatility of power supply costs and provide for annual adjustments to the rates charged to its retail customers. The power cost adjustment mechanisms compare Idaho Power's actual net power supply costs (primarily fuel and purchased power less wholesale energy sales) against net power supply costs being recovered in Idaho Power's retail rates. Under the power cost adjustment mechanisms, certain differences between actual net power supply costs incurred by Idaho Power and costs being recovered in retail rates are recorded as a deferred charge or credit on the balance sheet for future recovery or refund. The power supply costs deferred primarily result from changes in contracted power purchase prices and volumes, changes in wholesale market prices and transaction volumes, fuel prices, and the levels of Idaho Power's own generation.

In May ~~202~~20232,, the IPUC ~~approved a~~issued an order approving recovery of an incremental $200.2 million of ~~$94.9~~Idaho-jurisdiction PCA revenues, which included an increase in the forecasted power supply cost component and the deferral balance component. The IPUC directed Idaho Power to spread recovery of the $190.2 million ~~net~~deferral balance component of the PCA over a two-year period from June 1, 2023, to May 31, 2025, resulting in a total PCA increase of $105.1 million, ~~in Idaho-jurisdiction power cost adjustment (PCA) revenues,~~ effective for the ~~2022-2023~~ PCA collection period from June 1, ~~2022,~~2023, to May 31, ~~2023.~~2024. The order defers collection of $95.1 million of deferred PCA costs to the subsequent annual PCA collection period from June 1, 2024, to May 31, 2025. The net increase in PCA revenues ~~reflects a forecasted reduction in low-cost hydropower generation as well as~~reflects higher market energy ~~prices~~ and ~~higher~~ natural gas ~~prices.~~ prices, combined with lower-than-expected hydropower generation and limited coal supply in the

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prior April 2022 to March 2023 PCA period. The ~~filing~~net increase also ~~includes $0.6 million~~reflects an expectation of ~~2021 earnings~~continued elevated market energy and natural gas prices in the April 2023 to ~~be shared with customers~~March 2024 forecast period under the PCA.

In May ~~2018~~2023, the OPUC issued an order approving Idaho ~~Tax Reform Settlement Stipulation described above.~~Power's annual power cost update settlement, for a $7.7 million increase in Oregon-jurisdiction rates effective June 1, 2023.

Idaho Fixed Cost Adjustment Mechanism

The ~~Idaho jurisdiction fixed cost adjustment (FCA)~~Idaho-jurisdiction FCA mechanism, applicable to Idaho residential and small ~~general service~~commercial customers, is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour (kWh) charge and linking it instead to a set amount per customer. Under Idaho Power's current rate design, Idaho Power recovers a portion of fixed costs through the variable ~~kilowatt-hour~~kWh charge, which may result in over-collection or under-collection of fixed costs. To return over-collection to customers or to collect under-collection from customers, the FCA mechanism allows Idaho Power to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the year. The IPUC has discretion to cap the annual increase in the FCA recovery at 3 percent of base revenue, with any excess deferred for collection in a subsequent year. In May ~~2022,~~2023, the IPUC ~~approved~~issued an order approving a ~~decrease~~ ~~of $3.1~~$10.1 million decrease in recovery from the FCA from ~~$38.3~~$35.2 million to ~~$35.2~~$25.1 million for the ~~2021~~2022 FCA deferral, with new rates effective for the period from June 1, ~~2022,~~2023, to May 31, ~~2023.~~2024.

Jim Bridger Power Plant Rate Base Adjustment and Recovery

In June 2022, the IPUC issued an order approving, with modifications, Idaho Power’s amended application requesting authorization to ~~(a)~~(1) accelerate depreciation for the Jim Bridger plant to allow the coal-related plant assets to be fully depreciated and recovered by December 31, 2030, ~~(b)~~(2) establish a balancing account to track the incremental costs, benefits, and required regulatory accounting associated with ceasing participation in coal-fired operations at the Jim Bridger plant, and ~~(c) adjust~~(3) increase customer rates related to ~~recover~~ the associated incremental annual levelized revenue requirement (Bridger Order).

The Bridger Order allows for regulatory accounting entries and establishes balancing accounts (recorded as regulatory assets or liabilities on Idaho Power’s and IDACORP’s consolidated balance sheets) to track differences between amounts recovered in rates and actual incremental costs and benefits associated with Idaho Power’s cessation of coal-fired operations at the Jim Bridger plant.The incremental costs and benefits include the revenue requirement associated with the incremental Jim Bridger plant coal-related investments made from 2012 through the end of 2020, forecasted coal-related investments, and near-term decommissioning costs, offset by other operations and maintenance (O&M) cost savings. The Bridger Order deemed all coal-related investments at the Jim Bridger plant from 2012 through 2020 to be prudent for recovery. In the Bridger Order, the IPUC reduced Idaho Power's requested rate increase from 2.1 percent in its amended filing to 1.5 percent, a reduction from a requested $27.1 million to $18.8 million annually. The Bridger Order provides that any uncollected amount resulting from the reduction in the rate increase will be recorded in the balancing account for future recovery with no carrying charge. Uncollected amounts tracked in this balancing account were included for recovery in Idaho Power's June 1, 2023, general rate case filing with the IPUC. Idaho Power anticipates making future filings with the IPUC that may result in periodic adjustments to rates to true up variances between revenue collections and actual revenue requirement amounts.

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The Bridger Order allows Idaho Power to earn a return on and recover through 2030 the net book value of coal-related assets at the Jim Bridger plant as of December 31, 2020, as well as forecasted coal-related investments, which resulted in Idaho Power's deferral of certain depreciation expense during the three- and six-month periods ended June 30, 2022. The deferral and impacts of the Bridger Order resulted in an increase in net income for the first half of 2022 of approximately $9 million, all of which was recorded during the second quarter of 2022.investments.

Wildfire Mitigation Cost Recovery

In June 2021, the IPUC authorized Idaho Power to defer for future amortization incremental O&M and depreciation expense for certain capital investments necessary to implement Idaho Power's Wildfire Mitigation Plan (WMP). The IPUC also authorized Idaho Power to record these deferred expenses as a regulatory asset until Idaho Power can request amortization of the deferred costs in a future IPUC proceeding, at which time the IPUC will have the opportunity to review actual costs and determine the amount of prudently incurred costs that Idaho Power can recover through retail rates. In its 2021 application with the ~~filing,~~IPUC, Idaho Power projected spending approximately $47 million in incremental wildfire mitigation-related O&M and ~~approximately~~roughly $35 million in wildfire mitigation system-hardening incremental capital ~~incremental~~ expenditures over a five-year period. The IPUC authorized a deferral period of five years, or until rates go into effect from Idaho Power's next general rate case, whichever is first. As of June 30, ~~2022,~~2023, Idaho Power's deferral of Idaho-jurisdiction costs related to the WMP was ~~$14.8~~$39.5 million.

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updated WMP with the IPUC along with an application requesting authorization to defer an estimated $16 million of newly identified incremental costs expected to be incurred between 2022 and 2025 associated with expanded wildfire mitigation efforts. In March 2023, the IPUC approved Idaho Power's updated WMP and request to defer the additional incremental costs.

4. REVENUES

The following table provides a summary of electric utility operating revenues for IDACORP and Idaho Power for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands):


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Electric utility operating revenues:
Revenue from contracts with customers	Revenue from contracts with customers	$	345,483	$	357,461	$	663,665	$	648,787	Revenue from contracts with customers	$	385,229	$	345,483	$	770,895	$	663,665
Alternative revenue programs and other revenues	Alternative revenue programs and other revenues	12,185		1,597		37,924		25,838		Alternative revenue programs and other revenues	27,498		12,185		71,170		37,924
Total electric utility operating revenues	Total electric utility operating revenues	$	357,668	$	359,058	$	701,589	$	674,625	Total electric utility operating revenues	$	412,727	$	357,668	$	842,065	$	701,589

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Revenues from Contracts with Customers

The following table presents revenues from contracts with customers disaggregated by revenue source for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands):


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Revenues from contracts with customers:
Retail revenues:	Retail revenues:									Retail revenues:
Residential (includes $5,459, $(715), $15,551, and $15,107, respectively, related to the FCA)(1)		$	124,593	$	122,633	$	293,888	$	277,418
Commercial (includes $304, $165, $588, and $647, respectively, related to the FCA)(1)		79,260		77,609		157,826		149,878
Residential (includes $5,678, $5,459, $14,587, and $15,551, respectively, related to the FCA)(1)										Residential (includes $5,678, $5,459, $14,587, and $15,551, respectively, related to the FCA)(1)	$	134,885	$	124,593	$	323,422	$	293,888
Commercial (includes $296, $304, $572, and $588, respectively, related to the FCA)(1)										Commercial (includes $296, $304, $572, and $588, respectively, related to the FCA)(1)	87,677		79,260		175,507		157,826
Industrial	Industrial	51,987		48,047		101,047		93,477		Industrial	58,245		51,987		113,789		101,047
Irrigation	Irrigation	57,659		76,799		58,700		77,885		Irrigation	62,781		57,659		63,713		58,700

Deferred revenue related to HCC relicensing AFUDC(2)	Deferred revenue related to HCC relicensing AFUDC(2)	(1,927)		(1,927)		(4,046)		(4,046)		Deferred revenue related to HCC relicensing AFUDC(2)	(1,927)		(1,927)		(4,046)		(4,046)

Total retail revenues	Total retail revenues	311,572		323,161		607,415		594,612		Total retail revenues	341,661		311,572		672,385		607,415
Less: FCA mechanism revenues(1)	Less: FCA mechanism revenues(1)	(5,763)		550		(16,139)		(15,754)		Less: FCA mechanism revenues(1)	(5,974)		(5,763)		(15,159)		(16,139)
Wholesale energy sales	Wholesale energy sales	6,980		4,308		10,015		10,567		Wholesale energy sales	15,201		6,980		45,397		10,015
Transmission wheeling-related revenues	Transmission wheeling-related revenues	18,323		15,420		34,788		29,887		Transmission wheeling-related revenues	20,026		18,323		41,611		34,788
Energy efficiency program revenues	Energy efficiency program revenues	6,609		6,658		13,198		15,685		Energy efficiency program revenues	6,552		6,609		11,767		13,198
Other revenues from contracts with customers	Other revenues from contracts with customers	7,762		7,364		14,388		13,790		Other revenues from contracts with customers	7,763		7,762		14,894		14,388
Total revenues from contracts with customers	Total revenues from contracts with customers	$	345,483	$	357,461	$	663,665	$	648,787	Total revenues from contracts with customers	$	385,229	$	345,483	$	770,895	$	663,665

(1) The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers.

(2) The IPUC allows Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service.

Alternative Revenue Programs and Other Revenues

While revenues from contracts with customers make up most of Idaho Power’s revenues, the IPUC has authorized the use of an additional regulatory mechanism, the Idaho FCA mechanism, which may increase or decrease tariff-based customer rates. The Idaho FCA mechanism is described in Note 3 - "Regulatory Matters." The FCA mechanism revenues include only the initial recognition of FCA revenues when they meet the regulator-specified conditions for recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that Idaho Power initially recorded in prior periods when revenues met regulator-specified conditions. When Idaho Power includes those amounts in the price of utility service and billed to customers, Idaho Power records such amounts as recovery of the associated regulatory asset or liability and not as revenues.

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Derivative revenues include gains from settled electricity swaps and sales of electricity under forward sales contracts that are bundled with renewable energy credits. Related to these forward sales, Idaho Power simultaneously enters into forward purchases of electricity for the same quantity at the same location, which are recorded in purchased power on the condensed consolidated statements of income. For more information on settled electricity swaps, see Note 1211 - "Derivative Financial Instruments."

The table below presents the FCA mechanism revenues and other revenues for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands):


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Alternative revenue programs and other revenues:
FCA mechanism revenues	FCA mechanism revenues	$	5,763	(550)		$	16,139	$	15,754	FCA mechanism revenues	$	5,974	$	5,763	$	15,159	$	16,139
Derivative revenues	Derivative revenues	6,422		2,147		21,785		10,084		Derivative revenues	21,524		6,422		56,011		21,785
Total alternative revenue programs and other revenues	Total alternative revenue programs and other revenues	$	12,185	$	1,597	$	37,924	$	25,838	Total alternative revenue programs and other revenues	$	27,498	$	12,185	$	71,170	$	37,924

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Receivables and Allowance for Uncollectible Accounts

In response to the COVID-19 public health crisis, Idaho Power provided certain relief to customers, including temporarily suspending disconnections for customers and temporarily waiving late fees. This relief as well as the economic conditions created by the response to the COVID-19 public health crisis have resulted in higher aged accounts receivable and an increase in the number of late payments. Compared with historical levels, Idaho Power expects higher uncollectible account write-offs as a result of the COVID-19 public health crisis and, accordingly, has maintained its higher allowance for uncollectible accounts related to customer receivables at June 30, 2022.

The following table provides a ~~roll-forward~~rollforward of the allowance for uncollectible accounts related to customer receivables for the ~~three~~six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands):


		Six months ended June 30,							Six months ended June 30,
		2022			2021				2023			2022
Balance at beginning of period	Balance at beginning of period	$	4,499		$	4,766		Balance at beginning of period	$	5,034		$	4,499
Additions to the allowance	Additions to the allowance	478			369			Additions to the allowance	739			478
Write-offs, net of recoveries	Write-offs, net of recoveries	(1,056)			(883)			Write-offs, net of recoveries	(1,917)			(1,056)
Balance at end of period	Balance at end of period	$	3,921		$	4,252		Balance at end of period	$	3,856		$	3,921
Allowance for uncollectible accounts as a percentage of customer receivables	Allowance for uncollectible accounts as a percentage of customer receivables	4.3		%	4.8		%	Allowance for uncollectible accounts as a percentage of customer receivables	3.3		%	4.3		%

5. LONG-TERM DEBT

~~Term-Loan Credit~~Long-Term Debt Issuances and Redemptions

On December 22, 2022, Idaho Power entered into a Bond Purchase Agreement with certain institutional purchasers relating to the sale by Idaho Power of $170 million of first mortgage bonds, secured medium-term notes, Series N (Series N Notes), as described in Note 5 - "Long-Term Debt" to the consolidated financial statements included in the 2022 Annual Report. On March 8, 2023, Idaho Power issued $60 million in aggregate principal amount of 5.06% first mortgage bonds, secured medium-term notes, Series N, maturing on March 8, 2043; and $62 million in aggregate principal amount of 5.20% first mortgage bonds, secured medium-term notes, Series N, maturing on March 8, 2053.

Idaho Power also issues secured medium term notes from time to time under a shelf registration statement with the SEC, as described in Note 5 - "Long-Term Debt" to the consolidated financial statements included in the 2022 Annual Report. On March 14, 2023, under the shelf registration statement with the SEC, Idaho Power issued $400 million in aggregate principal amount of 5.50% first mortgage bonds, secured medium-term notes, Series M, maturing on March 15, 2053. On April 1, 2023, Idaho Power repaid $75 million in aggregate principal amount of maturing 2.50% first mortgage bonds due 2023,Series I.

On March 4, 2022, Idaho Power entered into a floating rate term loan credit agreement (Term Loan Facility)~~. The Term Loan Facility is a two-year senior unsecured delayed draw term loan facility used for general corporate purposes, including funding Idaho Power~~’~~s capital projects. It provided~~ for the issuance of ~~loans not~~up to ~~exceed the~~an aggregate principal amount of $150 million ~~with a maturity date~~due 2024, bearing interest at floating rates based on the Secured Overnight Financing Rate (SOFR), as described in Note 5 - "Long-Term Debt" to the consolidated financial statements included in the 2022 Annual Report. On March 31 and May 17, 2023, Idaho Power repaid $100 million and $50 million of ~~March 4, 2024. At June 30, 2022, $150 million in principal amount had been drawn and was outstanding on~~ the Term Loan Facility, respectively. As of June 30, 2023, there was no remaining outstanding principal balance of the Term Loan Facility.

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6. COMMON STOCK

IDACORP Common Stock

During the six months ended June 30, ~~2022,~~2023, IDACORP granted ~~73,131~~75,295 restricted stock ~~units~~unit awards to employees and issued ~~43,561~~52,897 shares of common stock using original issuances of shares pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan, including ~~8,674~~13,842 shares of common stock issued to members of the board of directors. As directed by IDACORP, plan administrators of the IDACORP, Inc. Dividend Reinvestment and Stock Purchase Plan and Idaho Power Company Employee Savings Plan used market purchases of IDACORP common stock to acquire shares of IDACORP common stock for the plans.

Restrictions on Dividends

Idaho Power’s ability to pay dividends on its common stock held by IDACORP and IDACORP’s ability to pay dividends on its common stock are limited to the extent payment of such dividends would violate the covenants in their respective ~~credit facilities~~Credit Facilities or Idaho Power’s Revised Code of Conduct. A covenant under IDACORP’s credit facility and Idaho Power’s credit facility requires IDACORP and Idaho Power to maintain leverage ratios of consolidated indebtedness to consolidated total capitalization, as defined therein, of no more than 65 percent at the end of each fiscal quarter. At June 30, ~~2022,~~2023, the leverage ratios for IDACORP and Idaho Power were 4447 percent and 4648 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to ~~$1.6~~$1.5 billion and ~~$1.3~~$1.4 billion, respectively, at June 30, ~~2022.~~2023. There are additional facility covenants, subject to exceptions, that prohibit or restrict the sale or disposition of property without consent and any agreements restricting dividend payments to IDACORP and Idaho Power from any material subsidiary. At June 30, ~~2022,~~2023, IDACORP and Idaho Power were in compliance with those ~~financial~~ covenants.

Idaho Power’s Revised Policy and Code of Conduct relating to transactions between and among Idaho Power, IDACORP, and other affiliates, which was approved by the IPUC in April 2008, provides that Idaho Power will not pay any dividends to IDACORP that will reduce Idaho Power’s common equity capital below 35 percent of its total adjusted capital without IPUC approval. At June 30, ~~2022,~~

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2023, Idaho Power's common equity capital was 5452 percent of its total adjusted capital. Further, Idaho Power must obtain approval from the OPUC before it can directly or indirectly loan funds or issue notes or give credit on its books to IDACORP.

Idaho Power’s articles of incorporation contain restrictions on the payment of dividends on its common stock if preferred stock dividends are in arrears. As of the date of this report, Idaho Power has no preferred stock outstanding.

In addition to contractual restrictions on the amount and payment of dividends, the Federal Power Act prohibits the payment of dividends from "capital accounts." The term "capital account" is undefined in the Federal Power Act or its regulations, but Idaho Power does not believe the restriction would limit Idaho Power's ability to pay dividends out of current year earnings or retained earnings.

7. EARNINGS PER SHARE

The table below presents the computation of IDACORP’s basic and diluted earnings per share for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands, except for per share amounts).


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Numerator:	Numerator:									Numerator:
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	$	64,287	$	70,023	$	110,548	$	114,854	Net income attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548
Denominator:	Denominator:									Denominator:
Weighted-average common shares outstanding - basic	Weighted-average common shares outstanding - basic	50,668		50,609		50,650		50,588		Weighted-average common shares outstanding - basic	50,725		50,668		50,707		50,650
Effect of dilutive securities	Effect of dilutive securities	19		13		23		13		Effect of dilutive securities	33		19		34		23
Weighted-average common shares outstanding - diluted	Weighted-average common shares outstanding - diluted	50,687		50,622		50,673		50,601		Weighted-average common shares outstanding - diluted	50,758		50,687		50,741		50,673
Basic earnings per share	Basic earnings per share	$	1.27	$	1.38	$	2.18	$	2.27	Basic earnings per share	$	1.35	$	1.27	$	2.46	$	2.18
Diluted earnings per share	Diluted earnings per share	$	1.27	$	1.38	$	2.18	$	2.27	Diluted earnings per share	$	1.35	$	1.27	$	2.46	$	2.18

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8. COMMITMENTS

Purchase Obligations

During the six months ended June 30, ~~2022,~~2023, Idaho Power entered into:

•~~1 new non-PURPA-qualifying solar~~an agreement in April 2023 to utilize the storage capacity of a 150-megawatt (MW) battery storage facility, ~~power purchase contract and 1 replacement PURPA-qualifying hydropower facility power purchase contract for an expiring power purchase agreement,~~subject to regulatory approval, which ~~collectively~~ increased Idaho Power's contractual purchase obligations by approximately ~~$86~~$430.9 million over the 20-year ~~terms~~term of the ~~contracts; and~~contract. The facility is scheduled to be online in June 2025;

•~~two new contracts~~an agreement in May 2023 to ~~acquire and own battery storage assets,~~replace an expiring PURPA-qualifying hydropower facility power purchase agreement, which ~~collectively~~ increased Idaho Power's contractual purchase obligations by approximately ~~$137~~$29.1 million over the 20-year term of the contract;

•an agreement in June 2023 to utilize up to one billion cubic feet of natural gas storage capacity, starting in April 2025, which increased Idaho Power's contractual purchase obligations by approximately $24.4 million over the 10-year term of the contract; and

•an agreement in June 2023 to acquire and own 36 MW of battery storage assets, which increased Idaho Power's contractual purchase obligations by approximately $52.6 million over the 1-year ~~terms~~term of the ~~contracts.~~contract. The batteries are scheduled to be online in the spring of 2024. During the six months ended June 30, ~~2022,~~2023, Idaho Power made payments of ~~$35~~$10.5 million related to ~~these obligations.~~this obligation.

~~Aside from these changes,~~In July 2023, Idaho Power entered into an agreement to meet certain environmental mitigation requirements in the State of Oregon for the Boardman-to-Hemingway transmission line project, which increased Idaho Power's contractual obligations by $16.9 million over the approximate 1-year term of the contract.

In July 2023, IFS committed to invest $35 million in an affordable housing tax credit project over an 18-year term.

Except as disclosed in this Note 8, during the six months ended June 30, 2023, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in the notes to the consolidated financial statements in the ~~2021~~2022 Annual Report.

Acquisition of Additional Interest in Boardman-To-Hemingway Transmission Project

In March 2023, Idaho Power executed a purchase, sale, and security agreement with the Bonneville Power Administration (BPA) to transfer BPA's 24 percent interest in the Boardman-to-Hemingway transmission line project to Idaho Power, bringing Idaho Power's interest in the project to 45 percent. Pursuant to the agreement, Idaho Power has a commitment to provide long-term transmission service to BPA. The agreement also required BPA to make a $10 million security payment to Idaho Power. On Idaho Power's condensed consolidated balance sheet, the agreement increased construction work in progress by $31.4 million for the acquired permitting interest, cash and cash equivalents by $10.0 million for the additional security payment, and other non-current liabilities by $41.4 million for Idaho Power's obligation to pay for the permitting interest and to return the security deposit to BPA. Payments to BPA for the permitting interest are expected to be made over a 15-year period beginning 10 years after energization of the transmission line project, while the security deposit is due to be returned to BPA upon energization.

Guarantees

Idaho Power guarantees its portion of reclamation activities and obligations at BCC, of which IERCo owns a one-third interest. This guarantee, which is renewed annually with the Wyoming Department of Environmental Quality, was ~~$50.8~~$47.3 million at June 30, ~~2022,~~2023, representing IERCo's one-third share of BCC's total reclamation obligation of ~~$152.5~~$141.9 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At June 30, ~~2022,~~2023, the value of BCC's reclamation trust fund was ~~$183.9~~$226.2 million. During the six months ended June 30, ~~2022,~~2023, the reclamation trust fund made ~~$1.1~~$2.2 million of distributions for reclamation activity costs associated with the BCC surface mine. BCC periodically assesses the adequacy of the reclamation trust fund and its estimate of future reclamation costs. To ensure that the reclamation trust fund maintains adequate reserves, BCC has the ability to, and does, add a per-ton surcharge to coal sales, all of which are made to the

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Jim Bridger plant. Because of the existence of the fund and the ability to apply a per-ton surcharge, the estimated fair value of this guarantee is minimal.

IDACORP and Idaho Power enter into financial agreements and power purchase and sale agreements that include indemnification provisions relating to various forms of claims or liabilities that may arise from the transactions contemplated by these agreements. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the

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overall maximum amount of the obligation under such indemnification provisions cannot be reasonably estimated. IDACORP and Idaho Power periodically evaluate the likelihood of incurring costs under such indemnities based on their historical experience and the evaluation of the specific indemnities. As of June 30, ~~2022, the companies~~2023, management believe the likelihood is remote that IDACORP or Idaho Power would be required to perform under such indemnification provisions or otherwise incur any significant losses with respect to such indemnification obligations. Neither IDACORP nor Idaho Power has recorded any liability on their respective condensed consolidated balance sheets with respect to these indemnification obligations.

9. CONTINGENCIES

IDACORP and Idaho Power have in the past and expect in the future to become involved in various claims, controversies, disputes, and other contingent matters, some of which involve litigation and regulatory or other contested proceedings. The ultimate resolution and outcome of litigation and regulatory proceedings is inherently difficult to determine, particularly where (a) the remedies or penalties sought are indeterminate, (b) the proceedings are in the early stages or the substantive issues have not been well developed, or (c) the matters involve complex or novel legal theories or a large number of parties. In accordance with applicable accounting guidance, IDACORP and Idaho Power, as applicable, establish an accrual for legal proceedings when those matters proceed to a stage where they present loss contingencies that are both probable and reasonably estimable. If the loss contingency at issue is not both probable and reasonably estimable, IDACORP and Idaho Power do not establish an accrual and the matter will continue to be monitored for any developments that would make the loss contingency both probable and reasonably estimable. As of the date of this report, IDACORP's and Idaho Power's accruals for loss contingencies are not material to their financial statements as a whole; however, future accruals could be material in a given period. IDACORP's and Idaho Power's determination is based on currently available information, and estimates presented in financial statements and other financial disclosures involve significant judgment and may be subject to significant uncertainty. For matters that affect Idaho Power's operations, Idaho Power intends to seek, to the extent permissible and appropriate, recovery through the ~~rate-making~~ratemaking process of costs incurred, although there is no assurance that such recovery would be granted.

IDACORP and Idaho Power are parties to legal claims and legal, tax, and regulatory actions and proceedings in the ordinary course of business and, as noted above, record an accrual for associated loss contingencies when they are probable and reasonably estimable. In connection with its utility operations, Idaho Power is subject to claims by individuals, entities, and governmental agencies for damages for alleged personal injury, property damage, and economic losses, relating to the company’s provision of electric service and the operation of its generation, transmission, and distribution facilities. Some of those claims relate to electrical contacts, service quality, property damage, ~~personal injury,~~ and wildfires. In recent years, utilities in the western United States have been subject to significant liability for personal injury, loss of life, property damage, trespass, and economic losses, and in some cases, punitive damages and criminal charges, associated with wildfires that originated from utility property, most commonly transmission and distribution lines. Idaho Power has also regularly received claims by governmental agencies and private landowners for damages for fires allegedly originating from Idaho Power’s transmission and distribution system. As of the date of this report, the companies believe that resolution of existing claims will not have a material adverse effect on their respective condensed consolidated financial statements.

Idaho Power is also actively monitoring various pending environmental regulations and executive orders related to environmental matters that may have a significant impact on its future operations. Given uncertainties regarding the outcome, timing, and compliance plans for these environmental matters, Idaho Power is unable to estimate the financial impact of these regulations.

10. BENEFIT PLANS

Idaho Power has a noncontributory defined benefit pension plan (pension plan) and two nonqualified defined benefit plans for certain senior management employees called the Security Plan for Senior Management Employees I and Security Plan for Senior Management Employees II (together, SMSP). Idaho Power also has a nonqualified defined benefit pension plan for directors that was frozen in 2002. Remaining vested benefits from that plan are included with the SMSP in the disclosures below. The benefits under the pension plan are based on years of service and the employee’s final average earnings. Idaho Power also maintains a defined benefit postretirement benefit plan (consisting of health care and death benefits) that covers all employees who were enrolled in the active-employee group plan at the time of retirement as well as their spouses and

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qualifying dependents. The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the three months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands).


		Pension Plan				SMSP				Postretirement Benefits				Total					Pension Plan				SMSP				Postretirement Benefits				Total
		2022		2021		2022		2021		2022		2021		2022		2021			2023		2022		2023		2022		2023		2022		2023		2022
Service cost	Service cost	$	12,849	$	13,693	$	297	$	203	$	266	$	179	$	13,412	$	14,075	Service cost	$	8,078	$	12,849	$	153	$	297	$	151	$	266	$	8,382	$	13,412
Interest cost	Interest cost	9,751		9,456		975		889		530		502		11,256		10,847		Interest cost	12,655		9,751		1,330		975		717		530		14,702		11,256
Expected return on plan assets	Expected return on plan assets	(18,137)		(16,024)		—		—		(585)		(597)		(18,722)		(16,621)		Expected return on plan assets	(15,434)		(18,137)		—		—		(407)		(585)		(15,841)		(18,722)
Amortization of prior service cost	Amortization of prior service cost	1		1		69		74		(2)		12		68		87		Amortization of prior service cost	1		1		55		69		417		(2)		473		68
Amortization of net loss	Amortization of net loss	2,589		6,225		1,058		1,052		(5)		—		3,642		7,277		Amortization of net loss	—		2,589		143		1,058		(346)		(5)		(203)		3,642
Net periodic benefit cost	Net periodic benefit cost	7,053		13,351		2,399		2,218		204		96		9,656		15,665		Net periodic benefit cost	5,300		7,053		1,681		2,399		532		204		7,513		9,656
Regulatory deferral of net periodic benefit cost(1)	Regulatory deferral of net periodic benefit cost(1)	(6,727)		(12,787)		—		—		—		—		(6,727)		(12,787)		Regulatory deferral of net periodic benefit cost(1)	(5,061)		(6,727)		—		—		—		—		(5,061)		(6,727)
Previously deferred pension costs recognized(1)	Previously deferred pension costs recognized(1)	4,289		4,289		—		—		—		—		4,289		4,289		Previously deferred pension costs recognized(1)	4,289		4,289		—		—		—		—		4,289		4,289
Net periodic benefit cost recognized for financial reporting(1)(2)	Net periodic benefit cost recognized for financial reporting(1)(2)	$	4,615	$	4,853	$	2,399	$	2,218	$	204	$	96	$	7,218	$	7,167	Net periodic benefit cost recognized for financial reporting(1)(2)	$	4,528	$	4,615	$	1,681	$	2,399	$	532	$	204	$	6,741	$	7,218

(1) Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates.

(2) Of total net periodic benefit cost recognized for financial reporting, ~~$5.0~~$5.1 million and ~~$4.5~~$5.0 million, respectively, were recognized in "Other operations and maintenance" and ~~$2.2~~$1.6 million and ~~$2.6~~$2.2 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the three months ended June 30, ~~2022~~2023 and ~~2021.~~2022.


The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the six months ended June 30, 2022 and 2021 (in thousands).
The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the six months ended June 30, 2023 and 2022 (in thousands).																		The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the six months ended June 30, 2023 and 2022 (in thousands).
		Pension Plan				SMSP				Postretirement Benefits				Total					Pension Plan				SMSP				Postretirement Benefits				Total
		2022		2021		2022		2021		2022		2021		2022		2021			2023		2022		2023		2022		2023		2022		2023		2022
Service cost	Service cost	$	26,013	$	27,101	$	593	$	406	$	536	$	532	$	27,142	$	28,039	Service cost	$	16,156	$	26,013	$	306	$	593	$	329	$	536	$	16,791	$	27,142
Interest cost	Interest cost	19,835		18,659		1,949		1,778		1,056		1,030		22,840		21,467		Interest cost	25,309		19,835		2,661		1,949		1,490		1,056		29,460		22,840
Expected return on plan assets	Expected return on plan assets	(36,174)		(32,045)		—		—		(1,176)		(1,198)		(37,350)		(33,243)		Expected return on plan assets	(30,868)		(36,174)		—		—		(826)		(1,176)		(31,694)		(37,350)
Amortization of prior service cost	Amortization of prior service cost	3		3		139		148		(3)		24		139		175		Amortization of prior service cost	3		3		110		139		833		(3)		946		139
Amortization of net loss	Amortization of net loss	6,137		11,898		2,115		2,103		(16)		—		8,236		14,001		Amortization of net loss	—		6,137		285		2,115		(618)		(16)		(333)		8,236
Net periodic benefit cost	Net periodic benefit cost	15,814		25,616		4,796		4,435		397		388		21,007		30,439		Net periodic benefit cost	10,600		15,814		3,362		4,796		1,208		397		15,170		21,007
Regulatory deferral of net periodic benefit cost(1)	Regulatory deferral of net periodic benefit cost(1)	(15,100)		(24,482)		—		—		—		—		(15,100)		(24,482)		Regulatory deferral of net periodic benefit cost(1)	(10,121)		(15,100)		—		—		—		—		(10,121)		(15,100)
Previously deferred pension costs recognized(1)	Previously deferred pension costs recognized(1)	8,577		8,577		—		—		—		—		8,577		8,577		Previously deferred pension costs recognized(1)	8,577		8,577		—		—		—		—		8,577		8,577
Net periodic benefit cost recognized for financial reporting(1)(2)	Net periodic benefit cost recognized for financial reporting(1)(2)	$	9,291	$	9,711	$	4,796	$	4,435	$	397	$	388	$	14,484	$	14,534	Net periodic benefit cost recognized for financial reporting(1)(2)	$	9,056	$	9,291	$	3,362	$	4,796	$	1,208	$	397	$	13,626	$	14,484

(2) Of total net periodic benefit cost recognized for financial reporting, ~~$9.9~~$10.4 million and ~~$9.3~~$9.9 million, respectively, were recognized in "Other operations and maintenance" and ~~$4.6~~$3.2 million and ~~$5.2~~$4.6 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the six months ended June 30, ~~2022~~2023 and ~~2021.~~2022.

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in ~~2022,~~2023, and during the six months ended June 30, ~~2022,~~2023, Idaho Power made a $10 million contribution. ~~In July 2022,~~ Idaho Power ~~made~~is considering contributing up to an additional ~~$10~~$30 million ~~contribution~~ to ~~the~~its defined benefit pension plan during 2023 in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions, ~~and~~as well as to mitigate the cost of being in an underfunded position. ~~Idaho Power is considering contributing up to an additional $20 million to its defined benefit pension plan during 2022.~~ The primary impact of pension contributions is on the timing of cash flows, as the timing of cost recovery lags behind contributions.

Idaho Power also has an Employee Savings Plan that complies with Section 401(k) of the Internal Revenue Code and covers substantially all employees. Idaho Power matches specified percentages of employee contributions to the Employee Savings Plan.

~~11. INVESTMENTS~~

Idaho Power has a rabbi trust designated to provide funding for obligations related to the SMSP. During the first quarter of 2022, the rabbi trust purchased $29.7 million of held-to-maturity investments in corporate fixed-income and asset-backed debt

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securities. Substantially all of these debt securities mature between 2027 and 2037. Held-to-maturity investments are carried at amortized cost, reflecting Idaho Power’s ability and intent to hold the securities to maturity. Held-to-maturity investments are adjusted for the amortization or accretion of premiums or discounts, which are amortized or accreted over the life of the related held-to-maturity security. Such amortization and accretion are included in the “Other income, net” line in the condensed consolidated statements of income. Due to increases in market interest rates in the first half of 2022, all held-to-maturity securities were in a gross unrealized holding loss position totaling $4.3 million at June 30, 2022. Based on ongoing credit evaluations of these holdings, Idaho Power does not expect payment defaults or delinquencies and has not recorded an allowance for credit losses for these securities as of June 30, 2022. Refer to Note 13 – “Fair Value Measurement” for additional information relating to the carrying amount and estimated fair value of the securities at the balance sheet date.

~~12.~~11. DERIVATIVE FINANCIAL INSTRUMENTS

Commodity Price Risk

Idaho Power is exposed to market risk relating to electricity, natural gas, and other fuel commodity prices, all of which are heavily influenced by supply and demand. Market risk may be influenced by market participants’ nonperformance of their contractual obligations and commitments, which affects the supply of or demand for the commodity. Idaho Power uses derivative instruments, such as physical and financial forward contracts, for both electricity and fuel to manage the risks relating to these commodity price exposures. The primary objectives of Idaho Power’s energy purchase and sale activity are to meet the demand of retail electric customers, maintain appropriate physical reserves to ensure reliability, and make economic use of temporary surpluses that may develop.

All of Idaho Power's derivative instruments have been entered into for the purpose of securing energy resources for future periods or economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges. Idaho Power offsets fair value amounts recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the same master netting agreement. Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's long-term derivative contracts, although Idaho Power's master netting arrangements would allow current and long-term positions to be offset in the event of default. Also, in the event of default, Idaho Power's master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table that follows.

The table below presents the gains and losses on derivatives not designated as hedging instruments for the three months and six months ended June 30, 2023 and 2022 ~~and 2021~~ (in ~~thousands).~~thousands of dollars):


				Gain/(Loss) on Derivatives Recognized in Income(1)															Gain/(Loss) on Derivatives Recognized in Income(1)
		Location of Realized Gain/(Loss) on Derivatives Recognized in Income		Three months ended June 30,						Six months ended June 30,							Location of Realized Gain/(Loss) on Derivatives Recognized in Income		Three months ended June 30,						Six months ended June 30,
			2022		2021			2022			2021							2023		2022			2023			2022
Financial swaps	Financial swaps		Operating revenues		$	(1,577)		$	—		$	(995)		$	—	Financial swaps		Operating revenues		$	5,042		$	(1,577)		$	3,963		$	(995)
Financial swaps	Financial swaps	Purchased power		(1,197)			—			(1,081)			249	Financial swaps			Purchased power		(1,733)			(1,197)			(107)			(1,081)
Financial swaps	Financial swaps	Fuel expense		2,991			903			4,451			1,636	Financial swaps			Fuel expense		(11,422)			2,991			12,114			4,451

Forward contracts	Forward contracts	Operating revenues		32			26			211			73	Forward contracts			Operating revenues		1,075			32			1,710			211
Forward contracts	Forward contracts	Purchased power		(31)			(26)			(210)			(73)	Forward contracts			Purchased power		(1,449)			(31)			(2,049)			(210)
Forward contracts	Forward contracts	Fuel expense		(9)			2			(62)			1	Forward contracts			Fuel expense		(19)			(9)			(439)			(62)

(1) Excludes unrealized gains or losses on derivatives, which are recorded on the balance sheet as regulatory assets or regulatory liabilities.

Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues or purchased power depending on the forecasted position being economically hedged by the derivative contract. Settlement gains and losses on contracts for natural gas are reflected in fuel expense. Settlement gains and losses on diesel derivatives are recorded in other O&M expense. See Note 1312 - "Fair Value Measurements" for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.

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Credit Risk

At June 30, ~~2022,~~2023, Idaho Power did not have material credit risk exposure from financial instruments, including derivatives. Idaho Power monitors credit risk exposure through reviews of counterparty credit quality, corporate-wide counterparty credit exposure, and corporate-wide counterparty concentration levels. Idaho Power manages these risks by establishing credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Idaho Power’s physical power contracts are commonly under WSPP, Inc. agreements, physical gas contracts are usually under North American Energy Standards Board contracts, and financial transactions are ~~generally~~usually under ~~standardized industry~~International Swaps and Derivatives Association, Inc. contracts. These contracts typically contain adequate assurance clauses requiring collateralization if a counterparty has debt that is downgraded below investment grade by at least one rating agency.

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Credit-Contingent Features

Certain of Idaho ~~Power~~Power's derivative instruments contain provisions that require Idaho Power's unsecured debt to maintain an investment grade credit rating from Moody's ~~Investors Service~~ and Standard & Poor's Ratings Services. If Idaho Power's unsecured debt were to fall below investment grade, it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment or demand immediate and ongoing full overnight collateralization on derivative instruments in net liability positions. ~~At June 30, 2022, the~~The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position at June 30, 2023, was ~~$9.3~~$33.7 million. Idaho Power posted ~~$1.2~~$44.4 million of cash collateral related to ~~this amount.~~its derivative instruments. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, ~~2022,~~2023, Idaho Power would have been required to pay or post collateral to its counterparties up to ~~$7.3~~an additional $9.2 million to cover ~~the~~ open liability positions as well as completed transactions that have not yet been paid.

Derivative Instrument Summary

The table below presents the fair values and locations of derivative instruments not designated as hedging instruments recorded on the balance sheets and reconciles the gross amounts of derivatives recognized as assets and as liabilities to the net amounts presented in the balance sheets at June 30, ~~2022,~~2023, and December 31, ~~2021~~2022 (in ~~thousands).~~thousands of dollars):


			Asset Derivatives							Liability Derivatives								Asset Derivatives							Liability Derivatives
		Balance Sheet Location	Gross Fair Value		Amounts Offset			Net Assets		Gross Fair Value		Amounts Offset		Net Liabilities			Balance Sheet Location	Gross Fair Value		Amounts Offset			Net Assets		Gross Fair Value		Amounts Offset			Net Liabilities

June 30, 2022
June 30, 2023																June 30, 2023
Current:	Current:															Current:
Financial swaps	Financial swaps	Other current assets	$	15,496	$	—		$	15,496	$	—	$	—	$	—	Financial swaps	Other current assets	$	344	$	(31)		$	313	$	31	$	(31)		$	—
Financial swaps	Financial swaps	Other current liabilities	9,052		(9,052)			—		9,229		(9,052)		177		Financial swaps	Other current liabilities	4,110		(4,110)			—		27,897		(21,648)		(1)	6,249

Forward contracts	Forward contracts	Other current liabilities	—		—			—		2,095		—		2,095		Forward contracts	Other current liabilities	—		—			—		2,066		—			2,066
Long-term:	Long-term:															Long-term:
Financial swaps	Financial swaps	Other assets	5,854		(1,509)			4,345		1,509		(1,509)		—		Financial swaps	Other assets	688		(348)			340		348		(348)			—

Financial swaps																Financial swaps	Other liabilities	371		(371)			—		2,075		(2,075)		(2)	—
Forward contracts	Forward contracts	Other liabilities	—		—			—		3,194		—		3,194		Forward contracts	Other liabilities	—		—			—		1,363		—			1,363
Total	Total		$	30,402	$	(10,561)		$	19,841	$	16,027	$	(10,561)	$	5,466	Total		$	5,513	$	(4,860)		$	653	$	33,780	$	(24,102)		$	9,678

December 31, 2021
December 31, 2022																December 31, 2022
Current:	Current:															Current:
Financial swaps	Financial swaps	Other current assets	$	10,599	$	(4,893)	(1)	$	5,706	$	2,910	$	(2,910)	$	—	Financial swaps	Other current assets	$	72,548	$	(32,609)	(3)	$	39,939	$	13,982	$	(13,982)		$	—
Financial swaps	Financial swaps	Other current liabilities	—		—			—		20		—		20		Financial swaps	Other current liabilities	132		(132)			—		1,577		(132)			1,445
Forward contracts	Forward contracts	Other current assets	6		(4)			2		4		(4)		—		Forward contracts	Other current assets	400		—			400		—		—			—
Forward contracts	Forward contracts	Other current liabilities	—		—			—		1,970		—		1,970		Forward contracts	Other current liabilities	—		—			—		2,071		—			2,071
Long-term:	Long-term:															Long-term:
Financial swaps	Financial swaps	Other assets	899		(9)			890		9		(9)		—		Financial swaps	Other assets	622		(43)			579		43		(43)			—
Financial swaps	Financial swaps	Other liabilities	—		—			—		14		—		14		Financial swaps	Other liabilities	644		(644)			—		2,136		(644)			1,492
Forward contracts	Forward contracts	Other liabilities	—		—			—		3,743		—		3,743		Forward contracts	Other liabilities	—		—			—		1,780		—			1,780
Total	Total		$	11,504	$	(4,906)		$	6,598	$	8,670	$	(2,923)	$	5,747	Total		$	74,346	$	(33,428)		$	40,918	$	21,589	$	(14,801)		$	6,788

(1) Current liability derivative amounts offset include $17.5 million of collateral receivable at June 30, 2023.

(2) Long-term liability derivative amounts offset include $1.7 million of collateral receivable at June 30, 2023.

(3) Current asset derivative amounts offset ~~includes $2.0~~include $18.6 million of collateral payable at December 31, ~~2021.~~2022.

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The table below presents the ~~volume~~volumes of derivative commodity forward contracts and swaps outstanding at June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands of units).:


			June 30,				June 30,
Commodity	Commodity	Units	2022	2021	Commodity	Units	2023	2022
Electricity purchases	Electricity purchases	MWh	541	254	Electricity purchases	MWh	792	541
Electricity sales	Electricity sales	MWh	118	10	Electricity sales	MWh	17	118
Natural gas purchases	Natural gas purchases	MMBtu	21,215	14,455	Natural gas purchases	MMBtu	35,545	21,215
Natural gas sales	Natural gas sales	MMBtu	—	75	Natural gas sales	MMBtu	310	—

~~13.~~12. FAIR VALUE MEASUREMENTS

IDACORP and Idaho Power have categorized their financial instruments into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). If the inputs used to measure the financial instruments fall within different levels of the hierarchy, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument.

Financial assets and liabilities recorded on the condensed consolidated balance sheets are categorized based on the inputs to the valuation techniques as follows:

• Level 1: Financial assets and liabilities whose values are based on unadjusted quoted prices for identical assets or liabilities in an active market that IDACORP and Idaho Power have the ability to access.

• Level 2: Financial assets and liabilities whose values are based on the following:

a) quoted prices for similar assets or liabilities in active markets;

b) quoted prices for identical or similar assets or liabilities in non-active markets;

c) pricing models whose inputs are observable for substantially the full term of the asset or liability; and

d) pricing models whose inputs are derived principally from or corroborated by observable market data through correlation or other means for substantially the full term of the asset or liability.

IDACORP and Idaho Power Level 2 inputs for derivative instruments are based on quoted market prices adjusted for location using corroborated, observable market data or using quoted ~~prices~~price which may be in non-active markets.

• Level 3: Financial assets and liabilities whose values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.

IDACORP’s and Idaho Power’s assessment of a particular input's significance to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy. There were no transfers between levels or material changes in valuation techniques or inputs during the six months ended June 30, ~~2022.~~2023.

Certain instruments have been valued using net asset value (NAV) as a practical expedient. ~~These instruments are similar to mutual funds; however, their~~The NAV is generally not published and publicly available, nor are these instruments traded on an exchange. Instruments valued using NAV as a practical expedient are included in the fair value disclosures below; however, in accordance with GAAP are not classified within the fair value hierarchy levels.

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The following table ~~below~~ presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of June 30, ~~2022,~~2023, and December 31, ~~2021~~2022 (in ~~thousands)~~thousands of dollars).


		June 30, 2022								December 31, 2021									June 30, 2023								December 31, 2022
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets:	Assets:																	Assets:
Money market funds
Money market funds and commercial paper																		Money market funds and commercial paper
IDACORP(1)	IDACORP(1)	$	76,279	$	—	$	—	$	76,279	$	80,406	$	—	$	—	$	80,406	IDACORP(1)	$	7,998	$	—	$	—	$	7,998	$	16,505	$	—	$	—	$	16,505
Idaho Power	Idaho Power	42,845		—		—		42,845		10,393		—		—		10,393		Idaho Power	43,909		—		—		43,909		34,468		—		—		34,468
Derivatives	Derivatives	19,841		—		—		19,841		6,596		2		—		6,598		Derivatives	653		—		—		653		40,518		400		—		40,918
Equity securities	Equity securities	27,408		—		—		27,408		54,431		—		—		54,431		Equity securities	31,617		—		—		31,617		34,129		—		—		34,129
IDACORP assets measured at NAV (not subject to hierarchy disclosure)(1)	IDACORP assets measured at NAV (not subject to hierarchy disclosure)(1)	—		—		—		2,063		—		—		—		1,363		IDACORP assets measured at NAV (not subject to hierarchy disclosure)(1)	—		—		—		3,236		—		—		—		2,796
Liabilities:	Liabilities:																	Liabilities:
Derivatives	Derivatives	177		5,289		—		5,466		34		5,713		—		5,747		Derivatives	6,249		3,429		—		9,678		2,937		3,851		—		6,788

(1) Holding company only. Does not include amounts held by Idaho Power.

Idaho Power’s derivatives are contracts entered into as part of its management of loads and resources. Electricity swap derivatives are valued on the Intercontinental Exchange (ICE) with quoted prices in an active market. Electricity forward contract derivatives are valued using a blend of two electricity exchanges, adjusted for location basis, as specified in the forward contract. Natural gas and diesel derivatives are valued using New York Mercantile Exchange (NYMEX) and ICE pricing, adjusted for location basis, which are also quoted under NYMEX and ICE pricing. Equity securities at Idaho Power consist of employee-directed investments related to an executive deferred compensation plan and actively traded money market and exchange traded funds related to the SMSP. The investments are measured using quoted prices in active markets and are held in a rabbi trust.

The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value, as of June 30, ~~2022,~~2023, and December 31, ~~2021,~~2022, using available market information and appropriate valuation methodologies (in ~~thousands)~~thousands of dollars).


		June 30, 2022				December 31, 2021					June 30, 2023				December 31, 2022
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
IDACORP	IDACORP									IDACORP
Assets:	Assets:									Assets:
Notes receivable(1)	Notes receivable(1)	$	3,804	$	3,804	$	3,804	$	3,804	Notes receivable(1)	$	3,871	$	3,871	$	3,871	$	3,871
Held-to-maturity securities~~(1)~~(2)	Held-to-maturity securities~~(1)~~(2)	29,308		24,959		—		—		Held-to-maturity securities~~(1)~~(2)	30,996		26,499		30,475		25,452
Liabilities:	Liabilities:									Liabilities:
Long-term debt, including current portion(1)		2,150,698		2,060,739		2,000,640		2,381,172
Long-term debt (including current portion)(1)										Long-term debt (including current portion)(1)	2,482,352		2,260,638		2,194,145		1,953,470
Idaho Power	Idaho Power									Idaho Power
Assets:	Assets:									Assets:
Held-to-maturity securities~~(1)~~(2)	Held-to-maturity securities~~(1)~~(2)	29,308		24,959		—		—		Held-to-maturity securities~~(1)~~(2)	$	30,996	$	26,499	$	30,475	$	25,452
Liabilities:	Liabilities:									Liabilities:
Long-term debt, including current portion(1)		2,150,698		2,060,739		2,000,640		2,381,172
Long-term debt (including current portion)(1)										Long-term debt (including current portion)(1)	2,482,352		2,260,638		2,194,145		1,953,470

(1) Notes receivable are categorized as Level 3 and held-to-maturity securities and long-term debt are categorized as Level 2 of the fair value hierarchy, as defined earlier in this Note 1312 - "Fair Value Measurements."

(2) All held-to-maturity securities are carried at amortized cost and were in a gross unrealized holding loss position totaling $4.5 million and $5.0 million as of June 30, 2023, and December 31, 2022, respectively. Substantially all of these debt securities mature between 2027 and 2037. Based on ongoing credit evaluations of these holdings, Idaho Power does not expect payment defaults or delinquencies and had not recorded an allowance for credit losses for these securities as of June 30, 2023 and 2022.

Notes receivable are related to Ida-West and are valued based on unobservable inputs, including forecasted cash flows, which are partially based on expected hydropower conditions. Held-to-maturity securities are held in a rabbi trust and are generally valued using quoted prices which may be in non-active ~~markets and are held in a rabbi trust.~~markets. Long-term debt is not traded on an exchange and is valued

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using quoted rates for similar debt in active markets. Carrying values for cash and cash equivalents, deposits, customer and other receivables, notes payable, accounts payable, interest accrued, and taxes accrued approximate fair value.

~~Table of Contents~~

~~14.~~13. SEGMENT INFORMATION

IDACORP’s only reportable segment is utility operations. The utility operations segment’s primary source of revenue is the regulated operations of Idaho Power. Idaho Power’s regulated operations include the generation, transmission, distribution, purchase, and sale of electricity. This segment also includes income from IERCo, a wholly-owned subsidiary of Idaho Power that is also subject to regulation and is a one-third owner of BCC, an unconsolidated joint venture.

IDACORP’s other operating segments are below the quantitative and qualitative thresholds for reportable segments and are included in the "All Other" category in the table below. This category is comprised of IFS’s investments in affordable housing and other real estate tax credit projects, Ida-West’s joint venture investments in small hydropower generation projects, and IDACORP’s holding company expenses.

The table below summarizes the segment information for IDACORP’s utility operations and the total of all other segments, and reconciles this information to total enterprise amounts (in thousands).


		Utility Operations		All Other		Eliminations		Consolidated Total			Utility Operations		All Other		Eliminations		Consolidated Total
Three months ended June 30, 2023:										Three months ended June 30, 2023:
Revenues										Revenues	$	412,727	$	1,111	$	—	$	413,838
Net income attributable to IDACORP, Inc.										Net income attributable to IDACORP, Inc.	67,080		1,494		—		68,574
Total assets as of June 30, 2023										Total assets as of June 30, 2023	7,747,117		211,650		(119,699)		7,839,068
Three months ended June 30, 2022:	Three months ended June 30, 2022:									Three months ended June 30, 2022:
Revenues	Revenues	$	357,668	$	1,055	$	—	$	358,723	Revenues	$	357,668	$	1,055	$	—	$	358,723
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	62,435		1,852		—		64,287		Net income attributable to IDACORP, Inc.	62,435		1,852		—		64,287
Total assets as of June 30, 2022		7,229,662		288,328		(65,894)		7,452,096
Three months ended June 30, 2021:
Six months ended June 30, 2023:										Six months ended June 30, 2023:
Revenues	Revenues	$	359,058	$	1,016	$	—	$	360,074	Revenues	$	842,065	$	1,432	$	—	$	843,497
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	68,822		1,201		—		70,023		Net income attributable to IDACORP, Inc.	122,790		1,882		—		124,672
Six months ended June 30, 2022:	Six months ended June 30, 2022:									Six months ended June 30, 2022:
Revenues	Revenues	701,589		$	1,422	$	—	$	703,011	Revenues	$	701,589	$	1,422	$	—	$	703,011
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	108,649		1,899		—		110,548		Net income attributable to IDACORP, Inc.	108,649		1,899		—		110,548
Six months ended June 30, 2021:
Revenues		674,625		$	1,502	$	—	$	676,127
Net income attributable to IDACORP, Inc.		113,191		1,663		—		114,854

~~15.~~14. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

The table below presents changes in components of accumulated other comprehensive income (AOCI), net of tax, during the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands). Items in parentheses indicate charges to AOCI.


		Defined Benefit Pension Items				Defined Benefit Pension Items					Defined Benefit Pension Items				Defined Benefit Pension Items
		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Balance at beginning of period	Balance at beginning of period	$	(39,203)	$	(42,522)	$	(40,040)	$	(43,358)	Balance at beginning of period	$	(12,776)	$	(39,203)	$	(12,922)	$	(40,040)
Amounts reclassified out of AOCI	Amounts reclassified out of AOCI	837		836		1,674		1,672		Amounts reclassified out of AOCI	147		837		293		1,674
Balance at end of period	Balance at end of period	$	(38,366)	$	(41,686)	$	(38,366)	$	(41,686)	Balance at end of period	$	(12,629)	$	(38,366)	$	(12,629)	$	(38,366)

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The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified during the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands). Items in parentheses indicate increases to net income.


		Amount Reclassified from AOCI									Amount Reclassified from AOCI
Details About AOCI	Details About AOCI	Three months ended June 30,				Six months ended June 30,				Details About AOCI	Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Amortization of defined benefit pension items(1)	Amortization of defined benefit pension items(1)									Amortization of defined benefit pension items(1)
Prior service cost	Prior service cost	$	69	$	74	$	139	$	148	Prior service cost	$	55	$	69	$	110	$	139
Net loss	Net loss	1,058		1,052		2,115		2,103		Net loss	143		1,058		285		2,115
Total before tax	Total before tax	1,127		1,126		2,254		2,251		Total before tax	198		1,127		395		2,254
Tax benefit(2)	Tax benefit(2)	(290)		(290)		(580)		(579)		Tax benefit(2)	(51)		(290)		(102)		(580)

Total reclassification for the period, net of tax	Total reclassification for the period, net of tax	$	837	$	836	$	1,674	$	1,672	Total reclassification for the period, net of tax	$	147	$	837	$	293	$	1,674

(1) Amortization of these items is included in IDACORP's condensed consolidated income statements in other operating expenses and in Idaho Power's condensed consolidated statements of income in other expense, net.

(2) The tax benefit is included in income tax expense in the condensed consolidated statements of income of both IDACORP and Idaho Power.

~~16.~~15. CHANGES IN IDAHO POWER RETAINED EARNINGS

The table below presents changes in Idaho Power retained earnings during the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands).


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Balance at beginning of period	Balance at beginning of period	$	1,704,320	$	1,607,583	$	1,696,304	$	1,599,155	Balance at beginning of period	$	1,891,898	$	1,704,320	$	1,836,547	$	1,696,304
Net income	Net income	62,435		68,822		108,649		113,191		Net income	67,080		62,435		122,790		108,649
Dividends to parent	Dividends to parent	(38,120)		(36,031)		(76,318)		(71,972)		Dividends to parent	(40,219)		(38,120)		(40,578)		(76,318)
Balance at end of period	Balance at end of period	$	1,728,635	$	1,640,374	$	1,728,635	$	1,640,374	Balance at end of period	$	1,918,759	$	1,728,635	$	1,918,759	$	1,728,635

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of IDACORP, Inc.

Results of Review of Interim Financial Information

We have reviewed the accompanying condensed consolidated balance sheet of IDACORP, Inc. and subsidiaries (the “Company”) as of June 30, ~~2022,~~2023, the related condensed consolidated statements of income, comprehensive income, and equity for the three-month and six-month periods ended June 30, ~~2022~~2023 and ~~2021,~~2022, and of cash flows for the six-month periods ended June 30, ~~2022~~2023 and ~~2021,~~2022, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of December 31, ~~2021,~~2022, and the related consolidated statements of income, comprehensive income, equity, and cash flows for the year then ended (not presented herein); and in our report dated February ~~17, 2022,~~16, 2023, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, ~~2021,~~2022, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of the Company’s management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ DELOITTE & TOUCHE LLP

Boise, Idaho

August ~~4, 2022~~3, 2023

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholder and the Board of Directors of Idaho Power Company

Results of Review of Interim Financial Information

We have reviewed the accompanying condensed consolidated balance sheet of Idaho Power Company and subsidiary (the “Company”) as of June 30, ~~2022,~~2023, the related condensed consolidated statements of income and comprehensive income for the three-month and six-month periods ended June 30, ~~2022~~2023 and ~~2021,~~2022, and of cash flows for the six-month periods ended June 30, ~~2022~~2023 and ~~2021,~~2022, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of December 31, ~~2021,~~2022, and the related consolidated statements of income, comprehensive income, retained earnings, and cash flows for the year then ended (not presented herein); and in our report dated February ~~17, 2022,~~16, 2023, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, ~~2021,~~2022, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

/s/ DELOITTE & TOUCHE LLP

Boise, Idaho

August ~~4, 2022~~3, 2023

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

In Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A) in this report, the general financial condition and results of operations for IDACORP, Inc. and its subsidiaries (collectively, IDACORP) and Idaho Power Company and its subsidiary (collectively, Idaho Power) are discussed. While reading the MD&A, please refer to the accompanying condensed consolidated financial statements of IDACORP and Idaho Power. Also refer to "Cautionary Note Regarding Forward-Looking Statements" in this report for important information regarding forward-looking statements made in this MD&A and elsewhere in this report. This discussion updates the MD&A included in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2021 (2021~~2022 (2022 Annual Report), and should also be read in conjunction with the information in that report. The results of operations for an interim period generally will not be indicative of results for the full year, particularly in light of the seasonality of Idaho Power's sales volumes, as discussed below.

INTRODUCTION

IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. IDACORP’s common stock is listed and trades on the New York Stock Exchange under the trading symbol "IDA". Idaho Power is an electric utility whose rates and other matters are regulated by the Idaho Public Utilities Commission (IPUC), Public Utility Commission of Oregon (OPUC), and Federal Energy Regulatory Commission (FERC). Idaho Power generates revenues and cash flows primarily from the sale and distribution of electricity to customers in its Idaho and Oregon service areas, as well as from the wholesale sale and transmission of electricity. Idaho Power experiences its highest retail energy sales during the summer irrigation and cooling season, with a lower peak in the winter that generally results from heating demand.

Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger ~~generating~~power plant (Jim Bridger plant) owned in part by Idaho Power. IDACORP’s other significant subsidiaries include IDACORP Financial Services, Inc., an investor in affordable housing and other real estate tax credit investments, and Ida-West Energy Company, an operator of small hydropower generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA).

EXECUTIVE OVERVIEW

Management's Outlook and Company ~~Initiatives~~Objectives

In the ~~2021~~2022 Annual Report, IDACORP's and Idaho Power's management included a summary of their business ~~strategies~~objectives for the companies for ~~2022~~2023 and beyond, under the heading "Executive Overview" in the MD&A. As of the date of this report, management's outlook and strategy remain consistent with that discussion, as updated by some of the discussion in this MD&A. ~~Most notably:~~Developments that have occurred since that report include the following:

•Idaho Power continues to execute on its four strategic areas and initiatives: growing financial strength, improving Idaho Power's core business, enhancing Idaho Power's brand, and focusing on safety and employee engagement.

•Idaho Power continues to expect positive customer growth in its service area. During the first six months of 2022, Idaho Power's customer count grew by over 7,600 customers, and for the twelve months ended June 30, 2022, the customer growth rate was 2.6 percent.

•Idaho Power anticipates substantial capital investments, with expected total capital expenditures of up to $2.8 billion over the five-year period from 2022 (including the expenditures incurred to-date in 2022) through 2026.

•Idaho Power continues to focus on timely recovery of costs and earning a reasonable return on ~~investment, including working~~investment. On June 1, 2023, Idaho Power filed a general rate case with the IPUC. The filing is described more fully in Note 3 - "Regulatory Matters" to ~~evaluate and ensure that its rate design and regulatory mechanisms more closely reflect~~ the ~~cost to provide electric service.~~condensed consolidated financial statements included in this report.

•In March 2023, Idaho Power ~~is committed~~executed an agreement with the Bonneville Power Administration (BPA) to ~~continuing~~transfer BPA's 24 percent interest in the Boardman-to-Hemingway 500-kV transmission line project to ~~provide reliable, affordable, safe service to its customers while furthering its environmental, social, and governance initiatives, including the "Clean Today. Cleaner Tomorrow.®" goal to provide~~Idaho Power, bringing Idaho Power's ~~customers with 100 percent clean energy by 2045, as well as water stewardship~~interest in the project to 45 percent. Further, in March 2023 the Oregon Supreme Court affirmed the Energy Facility Siting Council's (EFSC) order granting a site certificate for the Boardman-to-Hemingway transmission line project. In June 2023, both the IPUC and ~~environmental projects,~~OPUC granted certificates of public convenience and necessity (CPCN) related to the ~~company’s workforce recruiting, retention, and connection initiatives.~~construction of the Boardman-to-Hemingway transmission line.

•In April and May 2023, the IPUC approved Idaho Power's applications for revised special contracts for electric service between Idaho Power and two large industrial customers, which were modeled after Idaho Power's proposed Clean Energy Your Way program.

~~Notable for~~•In April 2023, the ~~second quarter,~~IPUC approved Idaho Power's 20-year power purchase agreement with Pleasant Valley Solar, LLC to purchase the output from a planned 200 megawatt (MW) solar facility, with a scheduled in-service date of March 2025. Idaho Power plans to sell that output exclusively to a large industrial customer under an agreement modeled after Idaho Power's proposed Clean Energy Your Way program.

•Also in April 2023, Idaho Power entered into a 20-year agreement to utilize the storage capacity from a 150-MW battery storage facility scheduled to be online in June ~~2022, the IPUC issued~~2025. Idaho Power intends for this capacity to supplement over 200 MW of company-owned storage that it expects to be online in 2023 and 2024, and an ~~order approving Idaho Power’s amended application requesting authorization to recover costs associated with its plan to cease participation~~additional 77 MW of company-owned storage it anticipates adding in ~~coal-fired operations at the Jim Bridger plant by 2028 (Bridger Order). For more information on the Bridger Order, see "Regulatory Matters" in this MD&A.~~

2025, pending regulatory approval. In July 2023, 80 MW of company-owned battery storage came online.

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•Idaho Power issued a formal request for proposals (RFP) in April 2023, soliciting bids for new energy and capacity resources as well as energy that can be delivered via transmission, beginning in 2026. The company’s long-range planning process has identified a potential need in 2026 and 2027 of approximately 350 MW of peak capacity, which could be met by approximately 1,100 MW of variable energy resources. The RFP provides that a portion of these resources may be transmitted via the Boardman-to-Hemingway transmission line project, which Idaho Power plans to have in-service as early as 2026.

Summary of Financial Results

The following is a summary of Idaho Power's net income, net income attributable to IDACORP, and IDACORP's earnings per diluted share for the three and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands, except earnings per share amounts):


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Idaho Power net income	Idaho Power net income	$	62,435	$	68,822	$	108,649	$	113,191	Idaho Power net income	$	67,080	$	62,435	$	122,790	$	108,649
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	$	64,287	$	70,023	$	110,548	$	114,854	Net income attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548
Weighted average outstanding shares – diluted	Weighted average outstanding shares – diluted	50,687		50,622		50,673		50,601		Weighted average outstanding shares – diluted	50,758		50,687		50,741		50,673
IDACORP, Inc. earnings per diluted share	IDACORP, Inc. earnings per diluted share	$	1.27	$	1.38	$	2.18	$	2.27	IDACORP, Inc. earnings per diluted share	$	1.35	$	1.27	$	2.46	$	2.18

The table below provides a reconciliation of net income attributable to IDACORP for the three and six months ended June 30, ~~2022,~~2023, from the same periods in ~~2021~~2022 (items are in millions and are before related income tax impact unless otherwise noted).:


		Three months ended			Six months ended				Three months ended			Six months ended
Net income attributable to IDACORP, Inc. - June 30, 2021			$	70.0		$	114.9
Net income attributable to IDACORP, Inc. - June 30, 2022								Net income attributable to IDACORP, Inc. - June 30, 2022		$	64.3		$	110.5
Increase (decrease) in Idaho Power net income:	Increase (decrease) in Idaho Power net income:							Increase (decrease) in Idaho Power net income:
Customer growth, net of associated power supply costs and power cost adjustment mechanisms	Customer growth, net of associated power supply costs and power cost adjustment mechanisms	2.7			5.8			Customer growth, net of associated power supply costs and power cost adjustment mechanisms	4.1			6.8
Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms	Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms	(25.9)			(15.8)			Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms	(1.7)			(1.2)
Idaho fixed cost adjustment (FCA) revenues	Idaho fixed cost adjustment (FCA) revenues	6.3			0.4			Idaho fixed cost adjustment (FCA) revenues	0.2			(1.0)
Retail revenues per megawatt-hour (MWh), net of associated power supply costs and power cost adjustment mechanisms	Retail revenues per megawatt-hour (MWh), net of associated power supply costs and power cost adjustment mechanisms	3.9			4.7			Retail revenues per megawatt-hour (MWh), net of associated power supply costs and power cost adjustment mechanisms	2.4			10.8
Transmission wheeling-related revenues	Transmission wheeling-related revenues	2.9			4.9			Transmission wheeling-related revenues	1.7			6.8

Other operations and maintenance (O&M) expenses	Other operations and maintenance (O&M) expenses	(12.0)			(18.5)			Other operations and maintenance (O&M) expenses	3.4			3.5
Depreciation expense	Depreciation expense	8.8			7.7			Depreciation expense	(12.3)			(13.2)
Other changes in operating revenues and expenses, net	Other changes in operating revenues and expenses, net	2.5			(0.1)			Other changes in operating revenues and expenses, net	3.0			(4.0)

Decrease in Idaho Power operating income		(10.8)			(10.9)

Increase in Idaho Power operating income								Increase in Idaho Power operating income	0.8			8.5
Non-operating expense, net	Non-operating expense, net	2.4			5.1			Non-operating expense, net	2.8			5.5

Income tax expense		2.1			1.3
Total decrease in Idaho Power net income			(6.3)			(4.5)
Additional accumulated deferred investment tax credits (ADITC) amortization								Additional accumulated deferred investment tax credits (ADITC) amortization	3.8			7.5
Income tax expense, excluding additional ADITC amortization								Income tax expense, excluding additional ADITC amortization	(2.8)			(7.4)
Total increase in Idaho Power net income								Total increase in Idaho Power net income		4.6			14.1
Other IDACORP changes (net of tax)	Other IDACORP changes (net of tax)		0.6			0.1		Other IDACORP changes (net of tax)		(0.3)			0.1
Net income attributable to IDACORP, Inc. - June 30, 2022			$	64.3		$	110.5
Net income attributable to IDACORP, Inc. - June 30, 2023								Net income attributable to IDACORP, Inc. - June 30, 2023		$	68.6		$	124.7

Net Income - Second Quarter ~~2022~~2023

IDACORP's net income ~~decreased $5.7~~increased $4.3 million for the second quarter of ~~2022~~2023 compared with the second quarter of ~~2021,~~2022, due primarily to ~~lower~~higher net income at Idaho Power. At Idaho Power, customer growth increased operating income by ~~$2.7~~$4.1 million in the second quarter of ~~2022~~2023 compared with the second quarter of ~~2021,~~2022, as the number of Idaho Power customers grew by approximately ~~15,500,~~13,100, or ~~2.6~~2.1 percent, during the twelve months ended June 30, ~~2022. Lower sales volumes on a per-customer basis in all~~2023. Usage per customer ~~classes~~ decreased operating income by ~~$25.9 million. Milder weather and greater precipitation~~$1.7 million in the second quarter of 2023 compared with the second quarter of 2022, due primarily to a 5 percent decrease in usage per industrial customer. In addition to slightly lower economic activity in a few industrial sectors, operation

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of a customer-owned-and-operated co-generation facility reduced industrial customer energy usage during the second quarter of 2023 compared with the second quarter of 2022 when ~~compared with~~ the ~~second quarter of 2021 led customers to use less energy per customer~~co-generation facility was down for irrigation pumping and air conditioning. The revenue impact of the decrease in sales volumes per customer was partially offset by the FCA mechanism (applicable to residential and small general service customers), which increased revenues in the second quarter of 2022 by $6.3 million compared with the second quarter of 2021.maintenance.

The net increase in retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms, increased operating income by $3.9 million during the second quarter of 2022 compared with the second quarter of 2021 due partially to the rate-related impact of monthly fixed charges being allocated over fewer MWh from the lower usage per customer, particularly among irrigation customers, described above. Also, a June 1, 2022 rate increase for Idaho Power’s Idaho

~~Table of Contents~~

retail customers related to the Bridger Order increased retail revenues per MWh during the second quarter of 2022 compared with the second quarter of 2021. For more information on the Bridger Order, see "Regulatory Matters" in this MD&A.

Transmission wheeling-related revenues increased $2.9 million during the second quarter of 2022 compared with the second quarter of 2021. Warmer weather in the southwest United States and milder weather in the Pacific Northwest during the second quarter of 2022 compared with the second quarter of 2021 led to a price spread between energy market hubs. This price spread increased third-party wheeling activity across Idaho Power's transmission system for transmission wheeling customers to access these markets in the second quarter of 2022 compared with the second quarter of 2021. Also, Idaho Power's open access transmission tariff (OATT) rates were approximately 4 percent higher in the second quarter of 2022 compared with the second quarter of 2021.

Other O&M expenses increased $12.0 million in the second quarter of 2022 compared with the second quarter of 2021 due to maintenance activities at the Jim Bridger coal plant, Langley Gulch natural gas plant, and American Falls hydropower project. Most of those maintenance activities are performed as scheduled maintenance, but not annually. Also, an increase in performance-based variable compensation accruals and inflationary pressures on labor-related costs, professional services, vehicle fuel, and supplies contributed to the increase in other O&M expenses in the second quarter of 2022 compared with the second quarter of 2021.

Depreciation expense decreased $8.8 million due primarily to the impacts of the Bridger Order from the IPUC authorizing Idaho Power to accelerate depreciation on, earn a return on, and recover through 2030 the net book value of coal-related assets at Idaho Power's jointly-owned Jim Bridger plant as of December 31, 2020, plus forecasted plant investments. The Bridger Order resulted in Idaho Power recording the deferral of certain depreciation expense in the second quarter of 2022. Idaho Power plans to cease participation in all coal-related operations at the Jim Bridger plant by 2028. Idaho Power expects the Bridger Order to increase operating revenues, net depreciation expense, and income tax expense in future periods and estimates the impacts of the Bridger Order will increase net income by approximately $10 million in 2023. Idaho Power expects the ongoing annual benefit to net income from the Bridger Order to decline each year through 2030, primarily due to the annual decline in Jim Bridger plant coal-related rate base, which Idaho Power expects to be fully depreciated by December 31, 2030. The Bridger Order is ~~described more fully in the "Regulatory Matters" section of this MD&A.~~

~~Net non-operating expense decreased~~ $2.4 million in the second quarter of ~~2022~~2023 compared with the second quarter of 2021. Allowance for funds used during construction (AFUDC) increased as the average construction work in progress balance was higher throughout the second quarter of 2022 compared with the second quarter of 2021 and, to a lesser extent, higher market interest rates led to higher interest income.

~~Idaho Power income tax expense for the second quarter of 2022 decreased by $2.1 million compared with the second quarter of 2021, primarily due to lower pre-tax income.~~

~~Net Income - Year-To-Date 2022~~

~~IDACORP's~~2022. The net income decreased $4.4 million for the first half of 2022 compared with the first half of 2021, due primarily to lower net income at Idaho Power. At Idaho Power, increases in sales volumes among all customer classes, except for irrigation customers, were due primarily to customer growth. Customer growth increased operating income by $5.8 million. Lower sales volumes on a per-customer basis, almost entirely related to irrigation customers, decreased operating income by $15.8 million in the first six months of 2022 compared with the same period of 2021. Milder weather and greater precipitation in Idaho Power's service area during the late spring and early summer when compared with the same seasons in 2021 led customers to use less energy per customer for irrigation pumping and, to a lesser extent, air conditioning. Higher sales per residential customer for heating from colder winter weather during the first quarter of 2022 were offset by weather-related declines in residential usage during the second quarter of 2022.

~~The~~ increase in retail revenues per MWh ~~net of associated power supply costs and power cost adjustment mechanisms, increased operating income by $4.7 million during the first half of 2022 compared with the first half of 2021,~~was primarily due ~~partially~~ to the ~~rate-related impact of monthly fixed charges being allocated over fewer MWh from the lower usage per customer, particularly among irrigation customers, described above. Also, a~~ June 1, 2022, rate increase for Idaho Power’s Idaho retail customers related to an order from the ~~Bridger Order increased retail revenues per MWh during the first half of 2022 compared with the first half of 2021.~~

Transmission wheeling-related revenues increased $4.9 million during the first half of 2022 compared with the first half of 2021. Warmer weather in the southwest United States and milder weather in the Pacific Northwest during the second quarter of 2022 compared with the second quarter of 2021 led to a price spread between energy market hubs. This price spread increased

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wheeling activity across Idaho Power's transmission system for wheeling customers to access these markets in the first half of 2022 compared with the first half of 2021. In addition, two new long-term wheeling agreements executed in April 2021 contributed to increased wheeling volumes during the first half of 2022 compared with the same period in 2021. Also, Idaho Power's OATT rates were approximately 4 percent higher in the first half of 2022 compared with the first half of 2021.

Other O&M expenses increased $18.5 million in the first half of 2022 compared with the first half of 2021, due largely to maintenance activities at the Jim Bridger coal plant, Langley Gulch natural gas plant, and American Falls hydropower project. Also, an increase in performance-based variable compensation accruals and inflationary pressures on labor-related costs, professional services, vehicle fuel, and supplies contributed to the increase in other O&M expenses in the first half of 2022 compared with the first half of 2021.

~~Depreciation expense decreased $7.7 million, due primarily to the impact of the Bridger Order described above in this MD&A, which~~IPUC that authorized Idaho Power to accelerate the depreciation on and recover through 2030 the net book value of coal-related assets at Idaho Power's jointly-owned Jim Bridger plant as of December 31, 2020, plus forecasted plant investments. For more information on the IPUC regulatory order related to the Jim Bridger Plant (Bridger Order), see Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2022 Annual Report.

Total other O&M expenses in the second quarter of 2023 were $3.4 million lower than the second quarter of 2022, due primarily to lower expenses from scheduled cyclical plant maintenance projects compared with the same period in 2022, offset partially by inflationary pressures on labor-related and other costs.

Depreciation expense increased $12.3 million in the second quarter of 2023 compared with the second quarter of 2022 due primarily to the notable impact in the second quarter of 2022 of the Bridger Order. The Bridger Order resulted in Idaho Power recording the deferral of certain depreciation expense in the second quarter of 2022. In addition, the increase in the second quarter of 2023 compared with the second quarter of 2022 is also partially due to an increase in plant-in-service.

Other changes in operating revenues and expenses, net, increased operating income by $3.0 million in the second quarter of 2023 compared with the second quarter of 2022, due primarily to a decrease in net power supply expenses that were not deferred for future recovery in rates through Idaho Power's power cost adjustment mechanisms. Lower wholesale natural gas and power market prices in the western United States decreased Idaho Power's net power supply expenses in the second quarter of 2023 compared with the second quarter of 2022.

Non-operating expense, net, decreased ~~$5.1~~$2.8 million in the second quarter of 2023 compared with the second quarter of 2022. Allowance for equity funds used during construction increased as the average construction work in progress balance was higher throughout the second quarter of 2023 compared with the second quarter of 2022. Also, interest income increased due to higher market interest rates. These increases were partially offset by higher interest expense on long-term debt in the second quarter of 2023 compared with the second quarter of 2022.

The decrease in income tax expense in the second quarter of 2023 compared with the second quarter of 2022 was principally the result of additional ADITC amortization, partially offset by higher pre-tax income. Based on Idaho Power's current expectations of full-year 2023 results, Idaho Power recorded $3.8 million of additional ADITC amortization under its Idaho regulatory settlement stipulation during the second quarter of 2023. Idaho Power currently expects to amortize up to $15 million of additional ADITC for the full-year 2023, but did not record any additional ADITC amortization in 2022.

Net Income - Year-To-Date 2023

IDACORP's net income increased $14.2 million for the first six months of 2023 compared with the first six months of 2022, due primarily to higher net income at Idaho Power. At Idaho Power, customer growth increased operating income by $6.8 million while usage per retail customer was relatively consistent in the first six months of 2023 compared with the first six months of 2022.

The net increase in retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms, increased operating income by $10.8 million in the first ~~half~~six months of ~~2022~~2023 compared with the first ~~half~~six months of ~~2021. AFUDC~~2022. The net increase in retail revenues per MWh was primarily due to the June 1, 2022, rate increase for Idaho Power’s Idaho retail customers related to the Bridger Order.

Transmission wheeling-related revenues increased $6.8 million during the first six months of 2023 compared with the first six months of 2022, resulting from Idaho Power's Open Access Transmission Tariff (OATT) rates being 1 percent higher and due to elevated energy prices in the western United States in the first quarter of 2023 compared with the first quarter of 2022.

Total other O&M expenses in the first six months of 2023 were $3.5 million lower than the first six months of 2022, due primarily to lower expenses from scheduled cyclical plant maintenance projects compared with the same period in 2022, as well as the timing of regulatory deferrals and payment credits received related to a jointly-funded project. These decreases in other O&M expenses were offset partially by inflationary pressures on labor-related and other costs.

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Depreciation expense increased $13.2 million due primarily to the impacts of the Bridger Order. The Bridger Order resulted in Idaho Power recording the deferral of certain depreciation expense in the second quarter of 2022. In addition, the increase is also partially due to an increase in plant-in-service.

Other changes in operating revenues and expenses, net, decreased operating income by $4.0 million in the first six months of 2023 compared with the first six months of 2022, due primarily to the net increase in net power supply expenses that were not deferred for future recovery in rates through Idaho Power's power cost adjustment mechanisms. Compared with the same periods of 2022, the increase in Idaho Power's net power supply expenses due to higher wholesale natural gas and power market prices in the western United States in the first quarter of 2023 was partially offset by the decrease in Idaho Power's net power supply costs due to lower wholesale natural gas and power market prices in the western United States in the second quarter of 2023.

Non-operating expense, net, decreased $5.5 million in the first six months of 2023 compared with the first six months of 2022. Allowance for equity funds used during construction increased as the average construction work in progress balance was higher throughout the first six months of ~~2022~~2023 compared with the first six months of ~~2021.~~2022. Also, interest income increased due to higher market interest ~~rates, and investment income increased related to life insurance claims in the rabbi trust for Idaho Power's nonqualified defined benefit pension plans,~~rates. These increases were partially offset by higher interest expense on long-term debt in the first ~~half~~six months of ~~2022~~2023 compared with the first ~~half~~six months of ~~2021.~~2022.

~~Idaho Power income~~Income tax expense ~~for~~in the first ~~half~~six months of ~~2022 decreased by $1.3 million compared~~2023 was consistent with the first ~~half~~six months of ~~2021, primarily due to lower~~2022 as increased taxes from higher pre-tax ~~income.~~income was more than offset by $7.5 million of additional ADITC amortization. Idaho Power did not record any additional ADITC amortization in 2022.

Overview of General Factors and Trends Affecting Results of Operations and Financial Condition

IDACORP's and Idaho Power's results of operations and financial condition are affected by a number of factors, and the impact of those factors is discussed in more detail below in this MD&A. To provide context for the discussion elsewhere in this report, some of the more notable factors are as follows:

•Economic Conditions and Loads: Economic conditions impact consumer demand for energy, revenues, collectability of accounts, the volume of wholesale energy sales, and the need to construct and improve infrastructure, purchase power, and implement programs to meet customer load demands. In recent years, Idaho Power has seen significant growth in the number of customers in its service area. Over the twelve months ended June 30, 2023, Idaho Power's customer count grew by 2.1 percent. While inflationary and volatile economic conditions could slow the rate of customer growth in the near-term, Idaho Power expects its number of customers and, to a greater extent its load due to anticipated commercial and industrial customer growth, to increase in the foreseeable future.

Idaho Power is preparing its 2023 Integrated Resource Plan (IRP), its 20-year forecast of power demand and supply options. The 2023 preliminary IRP assumptions include significant large commercial and industrial additions in the 5-year forecasted annual growth rate, including potential load from new facilities recently announced by Meta Platforms, Inc. and Micron. Included in the below table are Idaho Power's preliminary load forecast assumptions the company anticipates using in the 2023 IRP as of the date of this report, and for comparison purposes, the analogous average annual growth rates Idaho Power used in the prior two IRPs.


	5-Year Forecasted Annual Growth Rate		20-Year Forecasted Annual Growth Rate
	Retail Sales (Billed MWh)	Annual Peak (Peak Demand)	Retail Sales (Billed MWh)	Annual Peak (Peak Demand)
2023 IRP (preliminary)	5.5%	3.7%	2.2%	1.8%
2021 IRP	2.6%	2.1%	1.4%	1.4%
2019 IRP	1.3%	1.4%	1.0%	1.2%

Idaho Power believes that existing and sustained growth in customers, load, and peak demand for electricity, along with changes in the regional transmission markets that have constrained the availability of transmission outside Idaho Power’s service area to import energy during peak load periods, require Idaho Power to increase its investment in capacity resources, transmission, and distribution infrastructure. This includes the Boardman-to-Hemingway and Gateway West transmission projects, along with other capacity and energy resources contemplated by the procurement of resources described in the "Rate Base Growth and Infrastructure Investment" section below in this MD&A.

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•Rate Base Growth and Infrastructure Investment: The rates established by the IPUC, OPUC, and ~~OPUC~~FERC are determined with the intent to provide an opportunity for Idaho Power to recover authorized operating expenses and depreciation and earn a reasonable return on “rate base.” Rate base is generally determined by reference to the original cost (net of accumulated depreciation) of utility plant in service and certain other assets, subject to various adjustments for deferred income taxes and other items. Over time, rate base is increased by additions to utility plant in service and reduced by depreciation ~~and retirement~~ of utility plant and write-offs as authorized by the IPUC and OPUC. Idaho Power is pursuing significant enhancements to its utility infrastructure in an effort to maintain system reliability, ensure an adequate supply of electricity, and provide service to new customers, including major ongoing transmission projects such as the Boardman-to-Hemingway and Gateway West projects. Idaho Power's existing hydropower and thermal generation facilities also require continuing upgrades and equipment replacement, and the company is undertaking a significant relicensing effort for the Hells Canyon Complex (HCC), its largest hydropower generation resource. Idaho Power intends to pursue timely inclusion of any significant completed capital projects into rate base as part of a future general rate case or other appropriate regulatory proceeding.

~~Growth~~As noted previously, Idaho Power believes that existing and sustained growth in customers, load, and peak demand for electricity, ~~will require~~along with transmission constraints, has created the need for Idaho Power to ~~continue~~acquire significant generation and storage resources to ~~enhance its power supply, transmission,~~meet energy and ~~distribution infrastructure. While demand varies and is based on numerous factors, Idaho Power's 2021 Integrated Resource Plan (IRP) indicated Idaho Power may have a resource~~ capacity deficit for peak energy demand of 101 megawatts (MW) in 2023, an additional 85 MW deficit in 2024, and an additional 125 MW deficit in 2025. To help meet peak demand in 2023, Idaho Power has entered into contracts to purchase, own, and operate 120 MW of battery storage assets, and also entered into a 20-year power purchase agreement signed in February 2022 forneeds over the output of a planned third-party 40-MW solar facility. In March 2022, Idaho Power filed an application with the IPUC requesting approval of a revised special contract for electric service between Idaho Power and its existing customer Micron Technology, Inc. (Micron) under which Micron would purchase from Idaho Power the energy generated by the solar facility.

To help address the capacity deficits projected for 2024 and 2025, Idaho Power has been pursuing multiple options and issued a request for proposals (RFP) in December 2021. Depending on RFP results, timing of project in-service dates, and the outcome of regulatory proceedings,next several years. Idaho Power expects ~~it could invest over $400~~to spend more than $600 million ~~in capital expenditures~~ from ~~2022~~2023 through ~~2025 for~~2027 on resource additions to ~~help meet the~~address projected energy and capacity ~~deficits noted above.~~

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~~For more information on the 2021 IRP, including the load forecast assumptions Idaho Power used in its 2021 IRP, refer to "Resource Planning" in Item 1 - "Business" in Idaho Power's 2021 Annual Report.~~deficits. For more information about forecasted capital expenditures and expected rate base growth, see the "Liquidity and Capital Resources" section of this MD&A.

•Regulation of Rates and Cost ~~Recovery:~~Recovery; General Rate Case Filing: The prices that Idaho Power is authorized to charge for its electric and transmission service isare a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition. Those rates are established by state regulatory commissions and the FERC and are intended to allow Idaho Power an opportunity to recover its expenses and earn a reasonable return on investment. Idaho Power focuses on timely recovery of its costs through filings with its regulators, working to put in place innovative regulatory mechanisms, and prudent management of expenses and investments. Idaho Power has a regulatory settlement stipulation in Idaho that includes provisions for the accelerated amortization of ~~accumulated deferred investment tax credits (ADITC)~~ADITC to help achieve a minimum 9.4 percent Idaho-jurisdiction return on year-end equity (Idaho ROE). The settlement stipulation also provides for the potential sharing between Idaho Power and its Idaho customers of Idaho-jurisdictional earnings in excess of a 10.0 percent of Idaho ~~ROE.~~ROE, which would adjust to the authorized return on equity determined in the next general rate case. The settlement stipulation has no expiration date but the minimum Idaho ROE would revert back to 95 percent of the ~~allowed~~authorized return on equity determined in the next Idaho general rate case. The specific terms of the settlement stipulation are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the ~~2021~~2022 Annual Report. ~~With~~

Idaho Power filed a general rate case to adjust base customer rates in Idaho on June 1, 2023. Idaho Power expects a general rate case filing in Oregon likely to follow in late 2023 or 2024. The filing is described more fully in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. Several factors impacted Idaho Power’s ~~anticipated significant infrastructure investments, including those that are intended to help meet projected near-term capacity deficits,~~filing of its Idaho ~~Power believes that the appropriate time to file~~ general rate ~~cases~~case including the increase in ~~both Idaho and Oregon is approaching. The expected increase in~~depreciation expense from rate-base eligible assets as ~~these projects~~they are placed into service ~~along with~~(including its battery storage projects already placed in-service or expected to be in-service in 2023), the significant amounts of capital expenditures Idaho Power has made since its last general rate case filed in 2011, ~~impact Idaho Power’s need~~the expected financing costs for capital expenditures in a higher interest-rate environment, and, to ~~file, and~~a lesser extent, the timing of, general rate cases. In Idaho, Idaho Power is required to file a notice of its intent to file a general rate case with the IPUC at least 60 days before filing an application for a general rate case, andinflationary pressures on other O&M expenses described above. Idaho Power expects the processing of aits general rate case in Idaho ~~would~~will span at least seven months before new rates ~~would~~will be in effect. In Oregon, Idaho Power expects that processing of a general rate case would take approximately ten months.

•~~Economic Conditions and Loads~~: Economic conditions impact consumer demand for energy, revenues, collectability of accounts, the volume of wholesale energy sales, and the need to construct and improve infrastructure, purchase power, and implement programs to meet customer load demands. In recent years, Idaho Power has seen significant growth in the number of customers in its service area. Over the twelve months ended June 30, 2022, Idaho Power's customer count grew by 2.6 percent. Idaho Power expects its number of customers to continue to increase in the foreseeable future. Idaho Power also expects that existing and sustained growth in customers and peak demand for electricity will require Idaho Power to continue to enhance its capacity resources, transmission, and distribution infrastructure, including the Boardman-to-Hemingway and Gateway West transmission projects and the capacity and energy resources contemplated by the RFPs described above in this MD&A. That growth has resulted in the need for Idaho Power to procure additional sources of energy and capacity to serve growing demand and to maintain system reliability, as noted above. Further, recent changes in the regional transmission markets have constrained the transmission system external to Idaho Power's service area and impacted Idaho Power's ability to import energy from energy markets in the western United States during peak load periods. In order to meet growth in its service area, Idaho Power relies on numerous vendors to provide goods and services, and economic conditions have resulted in inflationary cost increases and supply chain constraints for numerous goods and services. Idaho Power has taken measures to help ensure the availability of supply chain-constrained items, such as distribution transformers and other electrical apparatus that are needed to serve new and existing customers, as it confronts continued strong customer growth amid an uncertain national and global economic environment.

•Weather Conditions: Weather and agricultural growing conditions have a significant impact on Idaho Power's energy sales. Relatively low and high temperatures result in greater energy use for heating and cooling, respectively. During the agricultural growing season, which in large part occurs during the second and third quarters of each year, irrigation customers use electricity to operate irrigation pumps, and weather conditions, such as a prolonged winter, can impact the timing and extent of use of those pumps. Idaho Power also has tiered rates and seasonal rates, which contribute to increased revenues during higher-load periods, most notably during the third quarter of each year when overall customer demand is highest. Much of the adverse or favorable impact of weather on sales of energy to residential and small commercial customers is mitigated through the Idaho FCA mechanism, which is described in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report.

Further, as Idaho Power's hydropower facilities comprise over one-half of Idaho Power's nameplate generation capacity, precipitation levels impact the mix of Idaho Power's generation resources. When hydropower generation

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decreases, Idaho Power must rely on more expensive generation sources and purchased power. When favorable hydropower generating conditions exist for Idaho Power, they also may exist for other Pacific Northwest hydropower facility operators, lowering regional wholesale market prices and impacting the revenue Idaho Power receives from wholesale energy sales. Much of the adverse or favorable impact of this volatility is addressed through the Idaho and Oregon power cost adjustment ~~mechanisms.~~mechanisms, which lessen the potential earnings benefit or detriment of volatile hydrological conditions and their impact on overall power supply costs. For ~~2022, due to relatively low reservoir storage carryover combined with the year's snowpack conditions, precipitation levels, and timing of run-off,~~2023, Idaho Power expects generation from its hydropower resources to be in the range of ~~5.0~~6.0 to ~~6.0~~7.5 million MWh, compared with 5.3 million MWh of hydropower generation in 2022 and a 30-year average annual total ~~annual hydropower generation~~ of ~~approximately~~ 7.7 million MWh.

•Mitigation of Impact of Fuel and Purchased Power Expense: In addition to hydropower generation, Idaho Power relies significantly on natural gas and coal to fuel its generation facilities and on power purchases in the wholesale markets. Fuel costs are impacted by electricity sales volumes, the terms and conditions of contracts for fuel, Idaho Power's generation capacity, the availability of hydropower generation resources, transmission capacity, energy market prices, and Idaho Power's hedging ~~program for managing~~of fuel and power costs. Purchased power costs are impacted by the terms and conditions of contracts for purchased power, the rate of expansion of alternative energy generation sources such as wind or solar energy, ~~hydropower~~ generation resource maintenance outages, and wholesale energy market prices. The Idaho and Oregon power cost adjustment mechanisms mitigate in large part the potential adverse earnings impacts to Idaho Power of fluctuations in power supply costs. Idaho Power also has an energy risk management and hedging program designed to mitigate some, but not all, of the price risk associated with volatile and elevated power supply and fuel costs. However, collection from customers or return to customers of most of the difference between actual power supply costs compared with those included in retail rates is deferred to a subsequent period, which can affect Idaho Power’s operating cash flow and liquidity until those costs are recovered from or returned to customers.

•Regulatory and Environmental Compliance ~~Costs:~~Costs; Coal Plant Retirements: Idaho Power is subject to extensive federal and state laws, policies, and regulations, as well as regulatory actions and audits by agencies and quasi-governmental agencies, including the FERC, the North American Electric Reliability Corporation, and the Western Electricity Coordinating Council. Compliance with these requirements directly influences Idaho Power's operating environment and affects Idaho Power's operating costs. ~~Energy industry regulators may issue substantial penalties for utilities alleged to have violated reliability and critical infrastructure protection requirements.~~ Moreover, environmental laws and regulations ~~in particular,~~ may increase the cost of constructing new facilities, may increase the cost of operating generation plants, may require that Idaho Power install additional pollution control devices at existing generating plants, may result in penalties for non-compliance, even where inadvertent, or may require that Idaho Power curtail or cease operating certain generation plants. Idaho Power expects to spend significant amounts on environmental compliance and controls infor the ~~next decade.~~foreseeable future. Due to economic factors in part associated with the costs of compliance with environmental regulation, Idaho Power accelerated the retirement date of its jointly-owned coal-fired generating plant in Valmy, Nevada (Valmy plant), ceasing coal-fired operations at one unit in 2019 and planning to cease its participation in coal-fired operations at the remaining unit by year-end 2025. ~~Idaho Power's jointly-owned coal plant in Boardman, Oregon, ceased operations as planned in October 2020.~~ In June 2022, the IPUC approved Idaho Power's request to allow the coal-related assets at the Jim Bridger plant to be fully depreciated and recovered by end-of-year 2030. The IPUC's Bridger Order related to Idaho Power's plan to cease its participation in coal-related operations at the Jim Bridger plant by 2028 isdescribed more fully in ~~the~~Note 3 - "Regulatory Matters" ~~section of~~to the condensed consolidated financial statements included in this ~~MD&A.~~report.

•Water Management and Relicensing of Hydropower Projects: Because of Idaho Power's reliance on stream flow in the Snake River and its tributaries, Idaho Power participates in numerous proceedings and venues that may affect its water rights, seeking to preserve the long-term availability of its rights for its hydropower projects. Also, Idaho Power is involved in renewing its long-term federal licenses for the HCC, its largest hydropower generation source, and for American Falls, its second largest hydropower generation source. Given the number of parties involved, Idaho Power's relicensing costs have been and are expected to continue to be substantial. As of the date of this report, Idaho Power cannot ~~currently~~ determine the ultimate terms of, and costs associated with, any resulting long-term licenses for the HCC or American Falls hydropower facilities.

•Wildfire Mitigation Efforts: In recent years, the western United States has experienced an increasing trend in the degree of annual destruction from wildfires. A variety of factors have contributed ~~in varying degrees~~ to this trend including climate change, increased wildland-urban interfaces, historical land management practices, and overall wildland and forest health. While Idaho Power has not experienced to-date the extent of catastrophic wildfires within its service area that have occurred in California and elsewhere in the western United States, Idaho Power is taking a proactive approach to wildfire threat in its service area and transmission corridors. Idaho Power has adopted a Wildfire Mitigation Plan (WMP) that outlines actions Idaho Power is taking or is working to implement in the future to reduce wildfire risk and to strengthen the resiliency of its transmission and distribution system to wildfires. Idaho Power's approach to achieve these objectives includes identifying areas subject to elevated risk; system hardening programs, vegetation

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management, and field personnel practices to mitigate wildfire risk; incorporating current and forecasted weather and field conditions into operational practices; public safety power shutoff protocols adopted in 2022; and evaluating the performance and effectiveness of the strategies identified in the WMP through metrics and monitoring. In regulatory orders received in June 2021 and March 2023, the IPUC authorized Idaho Power to defer, for future amortization, the Idaho jurisdictional share of

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actual incremental O&M expenses and depreciation expense of certain capital investments necessary to implement the WMP. The IPUC orders related to the WMP ~~case with the IPUC is~~are described in more detail in the "Regulatory Matters" section of this MD&A.

RESULTS OF OPERATIONS

This section of MD&A takes a closer look at the significant factors that affected IDACORP’s and Idaho Power’s earnings during the three months and six months ended June 30, ~~2022.~~2023. In this analysis, the results for the three months and six months ended June 30, ~~2022,~~2023, are compared with the same ~~period~~periods in ~~2021.~~2022.

The table below presents Idaho Power’s energy sales and supply (in thousands of MWh) for the three months and six months ended June 30, ~~2022~~2023 and ~~2021.~~2022.


		Three months ended June 30,		Six months ended June 30,			Three months ended June 30,		Six months ended June 30,
		2022	2021	2022	2021		2023	2022	2023	2022
Retail energy sales	Retail energy sales	3,648	4,098	7,273	7,467	Retail energy sales	3,694	3,648	7,385	7,273
Wholesale energy sales	Wholesale energy sales	121	67	149	188	Wholesale energy sales	330	121	538	149
Bundled energy sales		179	34	550	245
Energy sales bundled with renewable energy credits						Energy sales bundled with renewable energy credits	429	179	782	550
Total energy sales	Total energy sales	3,948	4,199	7,972	7,900	Total energy sales	4,453	3,948	8,705	7,972
Hydropower generation	Hydropower generation	1,602	1,449	2,866	2,875	Hydropower generation	2,430	1,602	3,805	2,866
Coal generation	Coal generation	777	372	1,595	908	Coal generation	180	777	608	1,595
Natural gas and other generation	Natural gas and other generation	179	666	638	1,307	Natural gas and other generation	307	179	1,187	638
Total system generation	Total system generation	2,558	2,487	5,099	5,090	Total system generation	2,917	2,558	5,600	5,099
Purchased power	Purchased power	1,723	1,949	3,504	3,346	Purchased power	1,856	1,723	3,756	3,504
Line losses	Line losses	(333)	(237)	(631)	(536)	Line losses	(320)	(333)	(651)	(631)
Total energy supply	Total energy supply	3,948	4,199	7,972	7,900	Total energy supply	4,453	3,948	8,705	7,972

Weather-related information for Boise, Idaho, for the three months and six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, is presented in the table below. While Boise, Idaho weather conditions are not necessarily representative of weather conditions throughout Idaho Power's service area, the greater Boise area has the majority of Idaho Power's customers and is included for illustrative purposes.


		Three months ended June 30,			Six months ended June 30,				Three months ended June 30,			Six months ended June 30,
		2022	2021	Normal (2)	2022	2021	Normal (2)		2023	2022	Normal (2)	2023	2022	Normal (2)
Heating degree-days(1)	Heating degree-days(1)	909	594	685	3,505	2,921	3,087	Heating degree-days(1)	577	909	685	3,169	3,505	3,087
Cooling degree-days(1)	Cooling degree-days(1)	157	383	188	157	383	188	Cooling degree-days(1)	246	157	188	246	157	188
Precipitation (inches)	Precipitation (inches)	4.6	2.5	3.4	7.3	6.3	7.2	Precipitation (inches)	3.0	4.6	3.4	6.7	7.3	7.2

(1) Heating and cooling degree-days are common measures used in the utility industry to analyze the demand for electricity and indicate when a customer would use electricity for heating and cooling. A degree-day measures how much the average daily temperature varies from 65 degrees. Each degree of temperature above 65 degrees is counted as one cooling degree-day, and each degree of temperature below 65 degrees is counted as one heating degree-day.

(2) Normal heating degree-days and cooling degree-days elements are, by convention, the arithmetic mean of the elements computed over 30 consecutive years. The normal amounts are the sum of the monthly normal amounts. These normal amounts are computed by the National Oceanic and Atmospheric Administration.

Sales Volume and Generation: Retail sales volumes ~~decreased 11~~increased 1 percent and 32 percent in the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods in ~~2021. Increases~~2022, primarily due to growth in ~~sales volumes from customer growth partially offset a decrease in sales volumes per customer during the second quarter of 2022, compared with the second quarter of 2021, as~~ the number of Idaho Power customers. The number of Idaho Power's customers grew by ~~2.6~~2.1 percent over the prior twelve ~~months. Increases in sales volumes among all customer classes, except for irrigation customers, were due primarily~~months, contributing to ~~customer growth, during~~ the first six months of 2022, compared with the first six months of 2021. Mild temperatures and greater precipitation caused customers to use less energy for irrigation and, to a lesser extent, air conditioning, particularly in the second quarter of 2022 compared with the second quarter of 2021. Precipitation in Boise Idaho was 86 percent higher during the three months ended June 30, 2022, compared with the same period of 2021, and 35 percent above normal, which decreased usage by irrigation customers by approximately 36 percent and 35 percent, respectively, during the three and six months ended June 30, 2022, compared with thevolumes.

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same periods in 2021. During the second quarter of 2022, usage per residential customer was approximately 10 percent lower and usage per commercial customer was approximately 6 percent lower than the same period of 2021, primarily due to cooler temperatures during the second quarter of 2022, which decreased the use of electricity for cooling purposes. Cooling degree-days in Boise, Idaho were 59 percent lower during the three months ended June 30, 2022, compared with the three months ended June 30, 2021, and 16 percent below normal. The weather-related declines in residential usage during the second quarter were almost entirely offset by the higher sales per residential customer that Idaho Power experienced from colder winter weather during the first quarter of 2022.

Total system generation increased 314 percent infor the second quarter and ~~was flat~~10 percent in the first six months of ~~2022~~2023 compared with the same periods in ~~2021. Hydropower~~2022, comprised of an increase in hydropower generation ~~increased 11 percent in the second quarter of 2022~~ and was slightly lower in the first six months of 2022 compared with the same periods in 2021, with the second-quarter increase due mostly to greater precipitation in the second quarter of 2022, and the overall decrease for the first six months of 2022 due largely to less snowpack and carry-over reservoir storage. Natural gas generation decreased significantly in the second quarter and first six months of 2022, respectively, compared with same periods of 2021, due primarily to a planned maintenance outage at the Langley Gulch natural gas plant and, to a lesser extent, higher natural gas market prices. This decrease in natural gas generation, ~~during~~partially offset by decreased coal generation. For more information on the ~~second quarter and first six months of 2022 led to a significant increase~~changes in ~~coal~~ generation, ~~and for~~see the ~~first six months of 2022, an increase~~"Operating Expenses" section below in ~~energy purchased from wholesale markets to help meet customer demand.~~this MD&A.

The financial impacts of fluctuations in wholesale energy sales, purchased power, fuel expense, and other power supply-related expenses are addressed in Idaho Power's Idaho and Oregon power cost adjustment mechanisms, which are described below in "~~Power~~"Power Cost Adjustment ~~Mechanisms~~Mechanisms." ~~in this MD&A.~~

Operating Revenues

Retail Revenues: The table below presents Idaho Power’s retail revenues (in thousands) and MWh sales volumes (in thousands) for the three months and six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, and the number of customers as of June 30, ~~2022~~2023 and ~~2021.~~2022.


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Retail revenues:	Retail revenues:									Retail revenues:
Residential (includes $5,459, $(715), $15,551, and $15,107, respectively, related to the FCA)(1)		$	124,593	$	122,633	$	293,888	$	277,418
Commercial (includes $304, $165, $588, and $647, respectively, related to the FCA)(1)		79,260		77,609		157,826		149,878
Residential (includes $5,678, $5,459, $14,587, and $15,551, respectively, related to the FCA)(1)										Residential (includes $5,678, $5,459, $14,587, and $15,551, respectively, related to the FCA)(1)	$	134,885	$	124,593	$	323,422	$	293,888
Commercial (includes $296, $304, $572, and $588, respectively, related to the FCA)(1)										Commercial (includes $296, $304, $572, and $588, respectively, related to the FCA)(1)	87,677		79,260		175,507		157,826
Industrial	Industrial	51,987		48,047		101,047		93,477		Industrial	58,245		51,987		113,789		101,047
Irrigation	Irrigation	57,659		76,799		58,700		77,885		Irrigation	62,781		57,659		63,713		58,700

Deferred revenue related to HCC relicensing AFUDC(2)	Deferred revenue related to HCC relicensing AFUDC(2)	(1,927)		(1,927)		(4,046)		(4,046)		Deferred revenue related to HCC relicensing AFUDC(2)	(1,927)		(1,927)		(4,046)		(4,046)

Total retail revenues	Total retail revenues	$	311,572	$	323,161	$	607,415	$	594,612	Total retail revenues	$	341,661	$	311,572	$	672,385	$	607,415
Volume of retail sales (MWh)	Volume of retail sales (MWh)									Volume of retail sales (MWh)
Residential	Residential	1,173		1,262		2,838		2,764		Residential	1,195		1,173		2,927		2,838
Commercial	Commercial	974		1,013		2,035		2,015		Commercial	990		974		2,062		2,035
Industrial	Industrial	852		856		1,737		1,708		Industrial	858		852		1,735		1,737
Irrigation	Irrigation	649		967		663		980		Irrigation	651		649		661		663
Total retail MWh sales	Total retail MWh sales	3,648		4,098		7,273		7,467		Total retail MWh sales	3,694		3,648		7,385		7,273
Number of retail customers at period end	Number of retail customers at period end									Number of retail customers at period end
Residential	Residential	512,594		498,747						Residential	524,191		512,594
Commercial	Commercial	76,573		75,187						Commercial	77,817		76,573
Industrial	Industrial	125		126						Industrial	132		125
Irrigation	Irrigation	22,063		21,811						Irrigation	22,309		22,063
Total customers	Total customers	611,355		595,871						Total customers	624,449		611,355

(1) The FCA mechanism is an alternative revenue program and does not represent revenue from contracts with customers.

(2) As part of its January 30, 2009 general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the HCC relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting approximately $8.8 million annually in the Idaho jurisdiction but is

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deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service.

Changes in rates, changes in customer usage, customer growth, and changes in FCA mechanism revenues are the primary reasons for fluctuations in retail revenues from period to period. The primary influences on customer usage of electricity are weather, economic conditions, and energy efficiency. Extreme temperatures increase sales to customers who use electricity for cooling and heating, while moderate temperatures decrease sales. Precipitation levels and the timing of precipitation during the agricultural growing season also affect sales to customers who use electricity to operate irrigation pumps. Rates are also seasonally adjusted, providing for higher rates during peak load periods, and residential customer rates are tiered, providing for higher rates based on higher levels of usage. The seasonal and tiered rate structures contribute to seasonal fluctuations in revenues and earnings.

Retail revenues ~~decreased $11.6~~increased $30.1 million and ~~increased $12.8~~$65.0 million during the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods in ~~2021.~~2022. The factors affecting retail revenues during ~~these~~the periods are discussed below.

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•~~Customers~~Rates: ~~Customer growth of 2.6 percent during~~Average customer rates, excluding amounts related to the ~~twelve~~power cost adjustment mechanisms, increased retail revenues by $2.4 million and $10.8 million, respectively, for the first three and six months ended June 30, 2023, compared with the same periods in 2022, due primarily to the June 1, 2022, rate increase for Idaho Power's retail customers related to the Bridger Order. Customer rates also include the collection from customers of amounts related to the power cost adjustment mechanisms, which increased ~~retail~~ revenues by ~~$4.2~~$22.7 million and ~~$8.9~~$44.4 million in the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods of 2022. The amount collected from customers in ~~2021.~~rates under the power cost adjustment mechanisms has relatively little effect on operating income as a corresponding amount is recorded as expense in the same period it is collected through rates.

•~~Usage~~Customers: ~~Lower usage (on a per customer basis), primarily related to irrigation customers, decreased~~Customer growth of 2.1 percent during the twelve months ended June 30, 2023, increased retail revenues by ~~$44.8~~$6.7 million and ~~$27.7~~$12.0 million in the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods of ~~2021. The~~2022.

•Usage: Decreased usage (on a per customer basis), primarily by industrial customers, decreased ~~usage~~retail revenues by ~~irrigation customers was primarily the result of greater precipitation~~$1.9 million and $1.2 million in ~~Idaho Power's service area during~~ the second quarter and first six months of ~~2022~~2023, respectively, compared with the same periods of ~~2021. Also, residential~~2022. Usage per industrial customer decreased 5 percent and ~~commercial customers used less energy per customer for cooling~~3 percent in the second quarter and first six months of ~~2022 primarily due~~2023, respectively, compared with the same periods of 2022. In addition to ~~milder temperatures~~slightly lower economic activity in a few industrial sectors in both periods in 2023, operation of a customer-owned-and-operated co-generation facility reduced industrial customer energy usage during the second quarter of 2023 compared with the second quarter of ~~2021. Higher sales per residential customer~~2022 when the co-generation facility was down for ~~heating from colder winter weather during the first quarter of 2022 were offset by weather-related declines in residential usage during the second quarter of 2022.~~maintenance.

•Idaho FCA Revenue: The FCA mechanism, applicable to Idaho residential and small commercial customers, adjusts revenue each year to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power through volume-based rates during the year. Lower usage (on a per customer basis) by residential and small ~~general service~~commercial customers during the second quarter ~~and first six months~~ of ~~2022~~2023 increased the amount of FCA revenue accrued by ~~$6.3~~$0.2 million ~~and $0.4 million, respectively,~~ compared with the same ~~periods~~period in ~~2021.~~

•~~Rates: Average~~2022. Higher usage (on a per customer ~~rates, excluding amounts related to~~basis) by residential and small commercial customers during the ~~power cost adjustment mechanisms, increased retail revenues by $8.7 million and $8.5 million, respectively, for the three and~~first six months ~~ended June 30, 2022,~~of 2023 decreased the amount of FCA revenue accrued by $1.0 million compared with the same ~~periods~~period in 2021, due partially to the rate-related impact of monthly fixed charges being allocated over fewer MWh from the lower usage per customer, particularly among irrigation customers, described above. Also, a June 1, 2022 rate increase for Idaho Power’s Idaho retail customers related to the Bridger Order increased retail revenues for the three and six months ended June 30, 2022, compared with the same periods of 2021. Customer rates also include the collection from customers of amounts related to the power cost adjustment mechanisms, which increased revenues by $14.1 million and $22.7 million in the second quarter and first six months of 2022, respectively, compared with the same periods of 2021. The amount collected from customers in rates under the power cost adjustment mechanisms has relatively little effect on operating income as a corresponding amount is recorded as expense in the same period it is collected through rates.2022.

Wholesale Energy Sales: Wholesale energy sales consist primarily of ~~opportunistic~~long-term sales contracts, sales of surplus system energy, ~~but also include~~and sales into the energy imbalance market in the western United States, ~~(Western EIM).~~and do not include derivative transactions. The table below presents Idaho Power’s wholesale energy sales for the three and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands, except for revenue per MWh amounts).

Three months ended
June 30, Six months ended
June 30,
2022 2021 2022 2021
Wholesale energy revenues $ 6,980 $ 4,308 $ 10,015 $ 10,567
Wholesale volume in MWh sold 121 67 149 188
Average wholesale energy revenues per MWh $ 57.69 $ 64.30 $ 67.21 $ 56.21


	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Wholesale energy revenues	$	15,201	$	6,980	$	45,397	$	10,015
Wholesale MWh sold	330		121		538		149
Wholesale energy revenues per MWh	$	46.06	$	57.69	$	84.38	$	67.21

~~Table~~In the second quarter and during the first six months of ~~Contents~~

~~Wholesale~~2023, wholesale energy revenues increased ~~$2.7~~$8.2 million ~~in the second quarter of 2022~~and $35.4 million, respectively, compared with the ~~second quarter~~same periods of ~~2021,~~2022, due primarily to increases in volumes sold. Wholesale MWh sold increased primarily due to higher hydro generation that resulted in more energy available for opportunistic market sales. The increase in wholesale volumes sold during the six months ended June 30, 2023, was also partially due to energy originally purchased under derivative forward contracts to be bundled with renewable energy credits, but the energy was ultimately sold in the wholesale markets in the first quarter of 2023. Those sales increased wholesale energy ~~sales volumes. Wholesale energy~~ revenues ~~were relatively flat~~by $16.7 million in the first six months of ~~2022 compared with~~2023 and a corresponding amount was recorded in purchased power on the ~~first six months~~condensed consolidated statements of ~~2021, as lower wholesale energy sales were mostly offset by higher wholesale market prices.~~income. The financial impacts of fluctuations in wholesale energy sales are largely mitigated by Idaho Power's Idaho and Oregon power cost adjustment mechanisms, which are described below in "~~Power~~this section of the MD&A under "Power Cost Adjustment ~~Mechanisms~~Mechanisms." ~~in this MD&A.~~

Transmission Wheeling-Related Revenues: Transmission wheeling-related revenues increased ~~$2.9~~$1.7 million, or 199 percent, and ~~$4.9~~$6.8 million, or 1620 percent, during the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods of ~~2021. Warmer weather~~2022, primarily due to elevated energy prices in the ~~southwest~~western United States and milder weather in the Pacific Northwest during the second quarter of 2022 compared with the second quarter of 2021 led to a price spread between energy market hubs. This price spread increased wheeling activity across Idaho Power's transmission system for wheeling customers to access these markets. In addition, two new long-term wheeling agreements executed in April 2021 contributed to increased wheeling volumes during the first half of 2022 compared with the same period in 2021.States. Also, Idaho Power's OATT rates were approximately 41 percent higher in the first half of ~~2022~~2023 compared ~~with~~to the first half of ~~2021.~~2022.

Energy Efficiency Program Revenues: In both Idaho and Oregon, energy efficiency riders fund energy efficiency program expenditures. Expenditures funded through the riders are reported as an operating expense with an equal amount recorded in revenues, resulting in no net impact on earnings. The cumulative variance between expenditures and amounts collected through the rider is recorded as a regulatory asset or liability. A liability balance indicates that Idaho Power has collected more than it

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has spent and an asset balance indicates that Idaho Power has spent more than it has collected. At June 30, ~~2022,~~2023, Idaho Power's energy efficiency rider balances were regulatory ~~assets~~liabilities of ~~$4.3~~$1.2 million in the Idaho jurisdiction and ~~$0.1~~$0.6 million in the Oregon jurisdiction.

Operating Expenses

Purchased Power: The table below presents Idaho Power’s purchased power expenses and volumes for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands, except for per MWh amounts).


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Expense	Expense									Expense
PURPA contracts	PURPA contracts	$	48,607	$	53,163	$	88,603	$	96,220	PURPA contracts	$	45,198	$	48,607	$	93,429	$	88,603
Other purchased power (including wheeling)	Other purchased power (including wheeling)	43,120		42,953		88,548		67,884		Other purchased power (including wheeling)	46,262		43,120		169,125		88,548
Total purchased power expense	Total purchased power expense	$	91,727	$	96,116	$	177,151	$	164,104	Total purchased power expense	$	91,460	$	91,727	$	262,554	$	177,151
MWh purchased	MWh purchased									MWh purchased
PURPA contracts	PURPA contracts	855		979		1,462		1,675		PURPA contracts	813		855		1,503		1,462
Other purchased power	Other purchased power	868		970		2,042		1,671		Other purchased power	1,043		868		2,253		2,042
Total MWh purchased	Total MWh purchased	1,723		1,949		3,504		3,346		Total MWh purchased	1,856		1,723		3,756		3,504
Average cost per MWh from PURPA contracts	Average cost per MWh from PURPA contracts	$	56.85	$	54.30	$	60.60	$	57.44	Average cost per MWh from PURPA contracts	$	55.59	$	56.85	$	62.16	$	60.60
Average cost per MWh from other sources	Average cost per MWh from other sources	$	49.68	$	44.28	$	43.36	$	40.62	Average cost per MWh from other sources	$	44.35	$	49.68	$	75.07	$	43.36
Weighted average - all sources	Weighted average - all sources	$	53.24	$	49.32	$	50.56	$	49.04	Weighted average - all sources	$	49.28	$	53.24	$	69.90	$	50.56

Purchased power expense decreased ~~$4.4~~$0.3 million ~~or 5 percent,~~ in the second quarter of 2023 compared with the second quarter of 2022, ~~but~~due primarily to a decrease in the weighted average purchased power prices compared with the second quarter of 2022. Purchased power expense increased ~~$13.0~~$85.4 million, or 848 percent, in the first six months of ~~2022~~2023 compared with the same ~~periods~~period of ~~2021. The decrease~~2022, due primarily to elevated wholesale energy prices in ~~purchased power expense for~~ the ~~second quarter was primarily due~~western United States and, to a ~~12 percent decrease in total MWh~~lesser extent, higher generation from projects under PURPA contracts and other purchased compared with the second quarter of 2021. Compared with the first six months of 2021, a decrease in natural gas generation during the first six months of 2022 led to a 5 percent increase in energy purchased from wholesale markets to help meet customer demand.power.

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Fuel Expense: The table below presents Idaho Power’s fuel expenses and thermal generation for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands, except for per MWh amounts).


		Three months ended June 30,				Six months ended June 30,					Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Expense	Expense									Expense
Coal	Coal	$	22,346	$	11,672	$	50,005	$	28,607	Coal	$	8,665	$	22,346	$	25,729	$	50,005
Natural gas	Natural gas	12,071		19,519		30,114		35,889		Natural gas	22,448		12,071		94,465		30,114
Total fuel expense	Total fuel expense	$	34,417	$	31,191	$	80,119	$	64,496	Total fuel expense	$	31,113	$	34,417	$	120,194	$	80,119
MWh generated	MWh generated									MWh generated
Coal	Coal	777		372		1,595		908		Coal	180		777		608		1,595
Natural gas	Natural gas	179		666		638		1,307		Natural gas	307		179		1,187		638
Total MWh generated	Total MWh generated	956		1,038		2,233		2,215		Total MWh generated	487		956		1,795		2,233
Average cost per MWh - Coal	Average cost per MWh - Coal	$	28.76	$	31.38	$	31.35	$	31.51	Average cost per MWh - Coal	$	48.14	$	28.76	$	42.32	$	31.35
Average cost per MWh - Natural gas	Average cost per MWh - Natural gas	$	67.44	$	29.31	$	47.20	$	27.46	Average cost per MWh - Natural gas	$	73.12	$	67.44	$	79.58	$	47.20
Weighted average, all sources	Weighted average, all sources	$	36.00	$	30.05	$	35.88	$	29.12	Weighted average, all sources	$	63.89	$	36.00	$	66.96	$	35.88

The majority of the fuel for Idaho Power’s jointly-owned coal-fired plants is purchased through long-term contracts, including purchases from BCC, a one-third owned joint venture of IERCo. The price of coal from BCC is subject to fluctuations in mine operating expenses, geologic conditions, and production levels. BCC supplies approximately two-thirds of the coal used by the Jim Bridger plant. Natural gas is mainly purchased on the regional wholesale spot market at published index prices. In addition to commodity (variable) costs, both natural gas and coal expenses include costs that are more fixed in nature for items such as

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capacity charges, transportation, and fuel handling. Period to period variances in fuel expense per MWh are noticeably impacted by these fixed charges when generation output is substantially different between the periods.

Fuel expense ~~increased $3.2~~decreased $3.3 million, or 10 ~~percent, and $15.6 million, or 24~~ percent, in the second quarter ~~and~~of 2023 compared with the second quarter of 2022, due primarily to a 52 percent increase in hydroelectric generation, which reduced Idaho Power's utilization of thermal generation. Fuel expense increased $40.1 million, or 50 percent, in the first six months of ~~2022, respectively,~~2023 compared with the same periods of ~~2021.~~2022, despite lower total thermal generation. The ~~increases~~increase in fuel expense ~~were~~in the first six months of 2023 compared with the same period of 2022, was primarily due to higher natural gas market prices in ~~2022,~~early 2023, which resulted in an increase in the average cost per MWh of natural gas generation. ~~Also, coal-fired~~The mix of Idaho Power's thermal generation ~~increased to compensate for~~between natural gas and coal in the ~~significant decrease~~second quarter and first half of 2023 compared with the same periods of 2022 was affected by fluctuations in natural gas prices and Idaho Power optimizing its dispatch of coal generation ~~primarily resulting from a planned maintenance outage at the Langley Gulch~~resources in an effort to help ensure adequate coal supply during its period of peak demand in 2023. To preserve coal supply for peak periods, Idaho Power relied more on natural ~~gas plant~~gas-fired generation to meet customer demand during the second quarter and first half of 2023 compared with the same periods in 2022.

Included in fuel expense are losses and gains on settled financial gas hedges entered into in accordance with Idaho Power's energy risk management policy. In the second quarter of 2023, losses on financial gas hedges of $11.4 million increased natural gas fuel expense, while in the second quarter of 2022 and ~~to a lesser extent, higher~~the first six months of 2023 and 2022, gains on financial gas hedges of $3.0 million, $12.1 million, and $4.5 million, respectively, reduced natural gas ~~market prices. Idaho Power expects natural gas market prices~~fuel expense. Most of these realized hedging losses and gains are passed on to ~~be volatile and to remain elevated~~customers through the ~~rest of 2022.~~power cost adjustment mechanisms described below.

Power Cost Adjustment Mechanisms: Idaho Power's power supply costs (primarily purchased power and fuel expense, less wholesale energy sales) can vary significantly from year to year. Volatility of power supply costs arises from factors such as weather conditions, wholesale market prices, volumes of power purchased and sold in the wholesale markets, Idaho Power's hydropower and thermal generation volumes and fuel costs, generation plant availability, and retail loads. To address the volatility of power supply costs, Idaho Power's power cost adjustment mechanisms in the Idaho and Oregon jurisdictions allow Idaho Power to recover from customers, or refund to customers, most of the fluctuations in power supply costs. The Idaho-jurisdiction power cost adjustment (PCA) includes a cost or benefit sharing ratio that allocates the deviations in net power supply expenses between customers (95 percent) and Idaho Power (5 percent), with the exception of PURPA power purchases and demand response program incentives, which are allocated 100 percent to customers. The Idaho deferral period, or PCA year, runs from April 1 through March 31. Amounts deferred or accrued during the PCA year are primarily recovered or refunded during the subsequent June 1 through May 31 period. ~~The primary financial impact~~However, the IPUC directed Idaho Power to spread recovery of the March 31, 2023 PCA deferral balance over a two-year periodfrom June 1, 2023, to May 31, 2025. Because of the power cost adjustment mechanisms, ~~relates~~the primary financial impacts of power supply cost variations are that cash is paid out but recovery from customers does not occur until a future period, or cash that is collected is refunded to ~~the timing of~~customers in a future period, resulting in fluctuations in operating cash flows ~~as cash may be paid out for power supply costs prior~~from year to ~~recovery from customers.~~year.

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The table that follows presents the components of the Idaho and Oregon power cost adjustment mechanisms for the three months and six months ended June 30, ~~2022~~2023 and ~~2021~~2022 (in thousands).

Three months ended
June 30, Six months ended
June 30,
2022 2021 2022 2021
Power supply cost (deferral) accrual $ (1,026) $ 866 $ 3,457 $ 16,126
Amortization of prior year authorized balances 600 (8,800) (4,282) (18,389)
Total power cost adjustment expense $ (426) $ (7,934) $ (825) $ (2,263)


	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Power supply cost accrual (deferral)	$	34,917	$	(1,026)	$	(25,351)	$	3,457
Oregon power supply cost accrual	312		—		336		—
Amortization of prior year authorized balances	14,400		600		23,307		(4,282)
Total power cost adjustment (income statement)	$	49,629	$	(426)	$	(1,708)	$	(825)

The power supply accruals (deferrals) ~~accruals~~ represent the portion of the power supply cost fluctuations accrued (deferred) ~~accrued~~ under the power cost adjustment mechanisms. When actual power supply costs are lower than the amount forecasted in power cost adjustment rates, most of the difference is accrued as an increase to a regulatory liability or decrease to a regulatory asset. When actual power supply costs are higher than the amount forecasted in power cost adjustment rates, most of the difference is deferred as an increase to a regulatory asset or decrease to a regulatory liability. During the second quarter of 2023, improved hydropower generation led to lower actual power supply costs compared with the forecasted amount, which resulted in an accrual of power supply costs by the mechanism. During the first six months of 2023, higher purchased power and fuel costs led to higher actual power supply costs compared with the forecasted amount, which resulted in an increase in the amount of power supply costs deferred by the mechanism. The amortization of the prior year’s balances represents the offset to the

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amounts being collected or refunded in the current power cost adjustment year that were deferred or accrued in the prior PCA year.

Other O&M Expenses: ~~Other~~Total other O&M expenses ~~increased $12.0~~decreased $3.4 million, or 143 percent, and ~~$18.5~~$3.5 million, or 112 percent, in the second quarter and first six months of ~~2022,~~2023, respectively, compared with the same periods of ~~2021,~~2022, due ~~largely~~primarily to lower expenses from scheduled cyclical plant maintenance ~~activities at~~projects compared with the Jim Bridger coal plant, Langley Gulch natural gas plant, and American Falls hydropower project. Most of those maintenance activities are performed as scheduled maintenance, but not annually. Also, an increasesame period in ~~performance-based variable compensation accruals and~~2022, offset partially by inflationary pressures on labor-related ~~costs, professional services, vehicle fuel,~~ and ~~supplies contributed to the increase in~~ other ~~O&M expenses.~~costs.

Income Taxes

~~Income tax expense for~~ IDACORP and Idaho Power ~~for~~income tax expense in the first six months ~~ended June 30,~~of 2023 was consistent with the first six months of 2022 ~~decreased~~as increased taxes from higher pre-tax income was more than offset by ~~$1.8~~$7.5 million ~~and $1.3 million, respectively, compared to the same period~~of additional ADITC amortization. Idaho Power did not record any additional ADITC amortization in ~~2021, primarily due to lower pre-tax income.~~2022. For information relating to IDACORP's and Idaho Power's computation of income tax expense, ~~effective income tax rates,~~ see Note 2 - "Income Taxes" to the condensed consolidated financial statements included in this report.

LIQUIDITY AND CAPITAL RESOURCES

Overview

Idaho Power continues to pursue significant enhancements to its utility infrastructure in an effort to ensure an adequate supply of electricity, to provide service to new customers, and to maintain system reliability. Idaho Power's existing hydropower and thermal generation facilities also require continuing upgrades and component replacement. Idaho Power anticipates these substantial capital expenditures will continue, with estimated total capital expenditures of up to $2.8 billion over the five-year period from 2022 (including expenditures incurred to-date in 2022) through 2026.

Idaho Power funds its liquidity needs for capital expenditures through cash flows from operations, debt offerings, commercial paper markets, credit facilities, a term loan facility, and capital contributions from IDACORP. Idaho Power periodically files for rate adjustments for recovery of operating costs and capital investments to provide the opportunity to align Idaho Power's earned returns with those allowed by regulators.

As of July ~~29, 2022,~~28, 2023, IDACORP's and Idaho Power's access to debt, equity, and credit arrangements included:

•their respective $100 million and $300 million revolving credit facilities;

•IDACORP's shelf registration statement filed with the U.S. Securities and Exchange Commission (SEC) on May 16, 2022, which may be used for the issuance of debt securities and common stock;

•Idaho Power's shelf registration statement filed with the SEC on May 16, 2022, which may be used for the issuance of first mortgage bonds and other debt securities; ~~$1.2 billion~~$630 million remains available for issuance pursuant to state regulatory authority; and

•IDACORP's and Idaho Power's issuance of commercial paper, which may be issued up to an amount equal to the available credit capacity under their respective ~~revolving~~ credit facilities.

46In March 2023, Idaho Power issued the following long-term debt with the proceeds being used for general corporate purposes, including repaying outstanding commercial paper and long-term debt and funding Idaho Power's capital projects:

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•$60 million of ~~Contents~~5.06% first mortgage bonds, secured medium-term notes, Series N, maturing in March 2043;

•$62 million of 5.20% first mortgage bonds, secured medium-term notes, Series N, maturing in March 2053; and

•$400 million of 5.50% first mortgage bonds, secured medium-term notes, Series M, maturing in March 2053.

In March through May 2023, a portion of the proceeds from the March 2023 issuances was used to repay outstanding commercial paper, $150 million in principal amount from a March 2022 term loan agreement, and $75 million in principal amount of maturing 2.50% first mortgage bonds, Series I.

In addition to the discussion above, which includes notable liquidity developments in 2023, more information on IDACORP's and Idaho Power's debt, equity, and credit facilities is included in Part II, Item 7 - "MD&A – Financing Programs and Available Liquidity" in the 2022 Annual Report.

IDACORP and Idaho Power monitor capital markets with a view toward opportunistic debt and equity transactions, taking into account current and potential future long-term needs. As a result, IDACORP may issue debt securities or common stock, and Idaho Power may issue ~~debt securities or~~ first mortgage bonds or other debt securities, if the companies believe terms available in the capital markets are favorable and that issuances would be financially prudent. Idaho Power also periodically analyzes whether partial or full early redemption of one or more existing outstanding series of first mortgage bonds is desirable, and in some cases, may refinance indebtedness with new indebtedness.

Based on planned capital expenditures and other O&M expenses, the companies believe they will be able to meet capital and debt service requirements and fund corporate expenses during at least the next twelve months with a combination of existing

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cash, operating cash flows generated by Idaho Power's utility business, availability under existing credit facilities, ~~and~~ access to commercial paper, short-term and long-term debt ~~markets.~~markets, and equity issuances.

IDACORP and Idaho Power generally seek to maintain capital structures of approximately 50 percent debt and 50 percent equity. Maintaining this ratio influences IDACORP's and Idaho Power's debt and equity issuance decisions. As of June 30, ~~2022,~~2023, IDACORP's and Idaho Power's capital structures, as calculated for purposes of applicable debt covenants, were as follows:


		IDACORP	Idaho Power		IDACORP	Idaho Power
Debt	Debt	44%	46%	Debt	47%	48%
Equity	Equity	56%	54%	Equity	53%	52%

IDACORP and Idaho Power ~~typically~~generally maintain their cash and cash equivalents in highly liquid investments, such as U.S. Treasury Bills, money market funds, and bank deposits.

At June 30, 2023, IDACORP and Idaho Power believed they were in compliance with all credit facility and long-term debt covenants. Further, IDACORP and Idaho Power do not anticipate they will be in violation or breach of their respective debt covenants during 2023.

Operating Cash Flows

IDACORP’s and Idaho Power's principal sources of cash flows from operations are Idaho Power's sales of electricity and transmission capacity. Significant uses of cash flows from operations include the purchase of fuel and power, other operating expenses, interest, income taxes, and plan contributions. Operating cash flows can be significantly influenced by factors such as weather conditions, rates and the outcome of regulatory proceedings, and economic conditions. As fuel and purchased power are significant uses of cash, Idaho Power has regulatory mechanisms in place that provide for the deferral and recovery of the majority of the fluctuation in those costs. However, if actual costs rise above the level currently allowed in retail rates, deferral balances increase (reflected as a regulatory asset), negatively affecting operating cash flows until such time as those costs, with interest, are recovered from customers.

IDACORP’s and Idaho Power’s operating cash inflows for the six months ended June 30, ~~2022,~~2023, were ~~$156~~$7 million and ~~$145~~$1 million, respectively, a decrease in cash flows from operations of ~~$11~~$149 million for IDACORP and $144 million for Idaho Power, when compared with the same period in ~~2021.~~2022. With the exception of cash flows related to income taxes, IDACORP's operating cash flows are principally derived from the operating cash ~~flow of~~flows from Idaho Power. Significant items that affected ~~the comparability of~~ the companies' operating cash flows in the first six months of ~~2022~~2023 when compared with the same period in ~~2021~~2022 were as follows:

•~~decreased~~a $14 million increase in IDACORP and Idaho Power net income;

•changes in regulatory assets and liabilities, mostly related to the relative amounts of costs deferred ~~taxes~~ and ~~taxes accrued~~collected under the Bridger Order and ~~receivable combined to decrease IDACORP and Idaho Power~~wildfire mitigation cost deferral, decreased operating cash flows by ~~$5 million~~$17 million; and ~~$3 million, respectively;~~

•changes in working capital balances due primarily to timing, including fluctuations ~~in accounts payable and other accrued liabilities, and other current assets~~ as follows:

◦~~timing of accounts payable and other accrued liability payments decreased operating cash flows by $26 million for IDACORP and Idaho Power, and~~

◦the changes in ~~other current assets increased~~materials, supplies, and fuel stock decreased operating cash flows by $31 million for IDACORP and Idaho Power, which was primarily due to ~~fluctuations~~an increase in ~~accrued unbilled revenues, the timing of purchases~~material and ~~consumption of materials and supplies, and~~supply inventory offset by the timing of purchases and consumption of coal at Idaho Power's jointly-owned coal-fired generating ~~plants.~~plants; and

◦the changes in accounts and wages payable decreased operating cash flows by $115 million for IDACORP and $113 million for Idaho Power, which was primarily due to an increase in power supply costs and associated timing of payments.

Investing Cash Flows

Investing activities consist primarily of capital expenditures related to new construction of, and improvements to, Idaho Power’s generation, transmission, and distribution facilities. IDACORP’s and Idaho Power’s net investing cash outflows for the six months ended June 30, ~~2022,~~2023, were ~~$204~~$264 million and ~~$175~~$263 million, respectively. Investing cash outflows for ~~2022~~2023 and ~~2021~~2022 were primarily for construction of utility infrastructure needed to address Idaho Power’s aging plant and equipment, customer growth, and environmental and regulatory compliance requirements. Significant items and transactions that affected investing cash flows ~~during~~in the first six months of ~~2022 and 2021~~2023 were as follows:

•~~IDACORP’s and Idaho Power’s investing cash outflows both included additions to utility plant of $194 million during the first half of 2022 compared with $128 million during the first half of 2021;~~

•~~IDACORP's investing cash outflows and inflows for 2022 and 2021 included $25 million in purchases of short-term investments and for 2021 included $50 million in sales of short-term investments;~~

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•~~IDACORP's~~IDACORP’s and Idaho Power’s investing cash outflows for ~~2022~~2023 included $274 million of additions to property, plant and ~~2021 included $3~~equipment, including $47 million spent on battery storage projects, and ~~$10~~at June 30, 2023, $49 million ~~respectively, of tax credit investments~~was accrued in ~~affordable housing and other real estate, which provide a return principally by reducing federal and state income taxes through tax credits and accelerated tax depreciation benefits;~~accounts payable on their consolidated balances sheets related to battery storage projects;

•~~IDACORP's~~IDACORP’s and Idaho Power's investing cash inflows for ~~2022~~2023 included $9 million from Boardman-to-Hemingway project joint permitting participants relating to a portion of the permitting expenditures and a security deposit;

•IDACORP’s and Idaho Power's investing cash outflows for 2023 included a ~~$10~~$5 million ~~return of~~ investment ~~from~~in IERCo, a wholly-owned subsidiary of Idaho Power; and

•~~IDACORP's~~IDACORP’s and Idaho Power's investing cash ~~outflows and~~ inflows for ~~2022~~2023 included ~~$27 million and $30 million, respectively, in purchases of equity and held-to-maturity securities, respectively, and $53~~$4 million in sales of equity securities, held in a rabbi trust, which is designated to provide funding for obligations related to Idaho Power's security plan for senior management employees.

Financing Cash Flows

Financing activities provide supplemental cash for both day-to-day operations and capital requirements, as needed. IDACORP's and Idaho Power's net financing cash inflows for the six months ended June 30, 2023, were $214 million and $257 million, respectively. Idaho Power funds liquidity needs for capital investment, working capital, managing commodity price risk, dividends, and other financial commitments through cash flows from operations, debt offerings, commercial paper markets, credit facilities, a term loan facility, and capital contributions from IDACORP. IDACORP funds its cash requirements, such as payment of taxes, payment of dividends, capital contributions to Idaho Power, and non-utility expenses allocated to IDACORP, through cash flows from operations, commercial paper markets, sales of common stock, and credit facilities.

~~IDACORP's~~ Significant items and ~~Idaho Power's net~~transactions that affected financing cash ~~inflows for the six months ended June 30, 2022, were $71 million and $74 million, respectively. During~~flows in the first six months of ~~2022,~~2023 were as follows:

•in March 2023, Idaho Power ~~drew $150~~repaid $100 million ~~from~~in principal amount of a ~~delayed draw~~March 2022 term loan ~~facility, described below,~~agreement;

•in March 2023, Idaho Power issued $60 million in principal amount of 5.06% first mortgage bonds, secured medium-term notes, Series N, maturing in March 2043;

•in March 2023, Idaho Power issued $62 million in principal amount of 5.20% first mortgage bonds, secured medium-term notes, Series N, maturing in March 2053;

•in March 2023, Idaho Power issued $400 million in principal amount of 5.50% first mortgage bonds, secured medium-term notes, Series M, maturing in March 2053;

•in April 2023, Idaho Power repaid, at maturity, $75 million in principal amount of 2.50% first mortgage bonds, secured medium-term notes, Series I;

•in May 2023, Idaho Power repaid $50 million in principal amount of a March 2022 term loan agreement; and

•IDACORP and Idaho Power paid dividends of ~~$76 million.~~

~~Financing Programs~~$81 million and ~~Available Liquidity~~

~~Term Loan Credit Agreement:~~

In March 2022, Idaho Power entered into a term loan credit agreement (Term Loan Facility). The Term Loan Facility is a two-year senior unsecured delayed draw term loan facility in the aggregate principal amount of $150 million. The maturity date of the Term Loan Facility is March 4, 2024. The Term Loan Facility which will be used for general corporate purposes, including funding Idaho Power's capital projects, provided for the issuance of loans in the aggregate principal amount of $150 million.

The interest rates for the floating rate advances under the Term Loan Facility were based on the highest of (1) the prime commercial lending rate of the lender acting as administrative agent, (2) the federal funds rate, plus 0.5 percent, (3) Term SOFR (as defined in the Term Loan Facility) for a one-month tenor that is published by CME Group Benchmark Administration limited (or the successor administrator of such rate), plus 1%, and (4) zero percent. The interest rates for SOFR Advances (as defined in the Term Loan Facility) were based on the Term SOFR rate for the borrower-selected period plus the Applicable Margin. The “Applicable Margin” is based on Idaho Power's senior unsecured non-credit enhanced long-term indebtedness credit rating, as set forth on a schedule to the Term Loan Facility.

~~At June 30, 2022, $150~~$41 million in ~~principal amount had been drawn and was outstanding on the Term Loan Facility.~~

~~IDACORP Equity Programs:~~ ~~IDACORP has no current plans to issue equity securities in 2022 other than under its equity compensation plans.~~2023, respectively.

~~Idaho Power First Mortgage Bonds~~: Idaho Power's issuance of long-term indebtedness is subject to the approval of the IPUC, OPUC, and Wyoming Public Service Commission (WPSC). In May and June 2022, Idaho Power received orders from the IPUC, OPUC, and WPSC authorizing the company to issue and sell from time to time up to $1.2 billion in aggregate principal amount of debt securities and first mortgage bonds, subject to conditions specified in the orders. Authority from the IPUC and WPSC is effective through May 31, 2025, subject to extension upon request to the IPUC and WPSC. The OPUC's order does not impose a time limitation for issuances, but does impose a number of other conditions, including a requirement that the interest rates for the debt securities or first mortgage bonds fall within either (a) designated spreads over comparable U.S. Treasury rates or (b) a maximum interest rate limit of eight percent.

In May 2022, Idaho Power filed a shelf registration statement with the SEC, which became effective upon filing, for the offer and sale of an unspecified principal amount of its first mortgage bonds. The issuance of first mortgage bonds requires that Idaho Power meet interest coverage and security provisions set forth in Idaho Power's Indenture of Mortgage and Deed of Trust, dated as of October 1, 1937, as amended and supplemented from time to time (Indenture). Future issuances of first mortgage bonds

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~~are subject to satisfaction of covenants and security provisions set forth in the Indenture, market conditions, regulatory authorizations, and covenants contained in other financing agreements.~~

In June 2022, Idaho Power entered into a selling agency agreement with six banks named in the agreement in connection with the potential issuance and sale from time to time of up to $1.2 billion aggregate principal amount of first mortgage bonds, secured medium term notes, Series M (Series M Notes), under Idaho Power’s Indenture of Mortgage and Deed of Trust, dated as of October 1, 1937, as amended and supplemented (Indenture). Also in June 2022, Idaho Power entered into the Fiftieth Supplemental Indenture, dated effective as of June 30, 2022, to the Indenture (Fiftieth Supplemental Indenture). The Fiftieth Supplemental Indenture provides for, among other items the issuance of up to $1.2 billion in aggregate principal amount of Series M Notes pursuant to the Indenture.

The Indenture limits the amount of first mortgage bonds at any one time outstanding to $2.5 billion, and as a result, the maximum amount of additional first mortgage bonds Idaho Power could issue as of June 30, 2022, was limited to approximately $534 million. Idaho Power plans to increase the $2.5 billion limit to $3.5 billion by filing a supplemental indenture with the trustee during the third quarter of 2022 as provided in the Indenture of Mortgage and Deed of Trust. Separately, the Indenture also limits the amount of additional first mortgage bonds that Idaho Power may issue to the sum of (a) the principal amount of retired first mortgage bonds and (b) 60 percent of total unfunded property additions, as defined in the Indenture. As of June 30, 2022, Idaho Power could issue approximately $2.2 billion of additional first mortgage bonds based on retired first mortgage bonds and total unfunded property additions.

~~IDACORP and Idaho Power Credit Facilities~~: IDACORP and Idaho Power have credit agreements for $100 million and $300 million credit facilities, respectively, which may be used for general corporate purposes and commercial paper back-up. IDACORP's facility permits borrowings under a revolving line of credit of up to $100 million at any one time outstanding, including swingline loans not to exceed $10 million at any one time and letters of credit not to exceed $50 million at any one time. IDACORP's facility may be increased, subject to specified conditions, to $150 million. Idaho Power's facility permits borrowings through the issuance of loans and standby letters of credit of up to $300 million at any one time outstanding, including swingline loans not to exceed $30 million at any one time and letters of credit not to exceed $50 million at any one time outstanding. Idaho Power's facility may be increased, subject to specified conditions, to $450 million. The credit facilities currently provide for a maturity date of December 6, 2025, though IDACORP and Idaho Power may request up to two-one-year extensions of the credit agreements, subject to certain conditions. Other terms and conditions of the credit facilities are described in the 2021 Annual Report, in Part II, Item 7 - "MD&A - Liquidity and Capital Resources."

Each facility contains a covenant requiring each company to maintain a leverage ratio of consolidated indebtedness to consolidated total capitalization equal to or less than 65 percent as of the end of each fiscal quarter. In determining the leverage ratio, "consolidated indebtedness" broadly includes all indebtedness of the respective borrower and its subsidiaries, including, in some instances, indebtedness evidenced by certain hybrid securities (as defined in the credit agreement). "Consolidated total capitalization" is calculated as the sum of all consolidated indebtedness, consolidated stockholders' equity of the borrower and its subsidiaries, and the aggregate value of outstanding hybrid securities. At June 30, 2022, the leverage ratios for IDACORP and Idaho Power were 44 percent and 46 percent, respectively. IDACORP's and Idaho Power's ability to utilize the credit facilities is conditioned upon their continued compliance with the leverage ratio covenants included in the credit facilities. There are additional covenants, subject to exceptions, that prohibit certain mergers, acquisitions, and investments, restrict the creation of certain liens, and prohibit entering into any agreements restricting dividend payments from any material subsidiary.

At June 30, 2022, IDACORP and Idaho Power believed they were in compliance with all facility covenants. Further, IDACORP and Idaho Power do not anticipate they will be in violation or breach of their respective debt covenants during 2022.

~~Without additional approval from the IPUC, the OPUC, and the WPSC, the aggregate amount~~ ~~of short-term borrowings up to three years by Idaho Power at any one time outstanding may not exceed $450 million. Idaho Power has obtained approval of the IPUC, the OPUC, and the WPSC for the issuance of short-term borrowings through December 2026.~~

~~IDACORP and Idaho Power Commercial Paper:~~ IDACORP and Idaho Power have commercial paper programs under which they issue unsecured commercial paper notes up to a maximum aggregate amount outstanding at any time not to exceed the available capacity under their respective revolving credit facilities, described above. IDACORP's and Idaho Power's revolving credit facilities are available to the companies to support borrowings under their commercial paper programs. The commercial paper issuances are used to provide an additional financing source for the companies' short-term liquidity needs. The maturities of the commercial paper issuances will vary but may not exceed 270 days from the date of issue. Individual instruments carry a fixed rate during their respective terms, although the interest rates are reflective of current market conditions, subjecting the companies to fluctuations in interest rates.

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Available Short-Term Borrowing Liquidity

The table below outlines available short-term borrowing liquidity as of the dates specified (in thousands).


		June 30, 2022				December 31, 2021					June 30, 2023				December 31, 2022
		IDACORP(2)		Idaho Power		IDACORP(2)		Idaho Power			IDACORP(2)		Idaho Power		IDACORP(2)		Idaho Power
Revolving credit facility	Revolving credit facility	$	100,000	$	300,000	$	100,000	$	300,000	Revolving credit facility	$	100,000	$	300,000	$	100,000	$	300,000
Commercial paper outstanding	Commercial paper outstanding	—		—		—		—		Commercial paper outstanding	—		—		—		—
Identified for other use(1)	Identified for other use(1)	—		(24,245)		—		(24,245)		Identified for other use(1)	—		(19,885)		—		(19,885)
Net balance available	Net balance available	$	100,000	$	275,755	$	100,000	$	275,755	Net balance available	$	100,000	$	280,115	$	100,000	$	280,115

(1) ~~Port of Morrow and~~ American Falls bonds that Idaho Power could be required to purchase prior to maturity under the optional or mandatory purchase provisions of the bonds, if the remarketing agent for the bonds is unable to sell the bonds to third parties.

(2) Holding company only.

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On July ~~29, 2022,~~28, 2023, IDACORP and Idaho Power had no loans outstanding under ~~its~~their revolving credit facilities and had no commercial paper outstanding. ~~Idaho Power also had no loans outstanding under its revolving credit facilities and no~~The table below presents additional information about short-term commercial paper ~~outstanding at that date. During~~borrowing during the three and six months ended June 30, ~~2022, IDACORP and Idaho Power issued no short-term commercial paper.~~2023.


	Three months ended June 30, 2023						Six months ended June 30, 2023
	IDACORP(1)			Idaho Power			IDACORP(1)			Idaho Power
Commercial Paper:
Period end:
Amount outstanding	$	—		$	—		$	—		$	—
Weighted average interest rate	—		%	—		%	—		%	—		%
Daily average amount outstanding during the period	$	—		$	—		$	—		$	18,554
Weighted average interest rate during the period	—		%	—		%	—		%	4.94		%
Maximum month-end balance	$	—		$	—		$	—		$	110,000

(1) Holding company only.

Impact of Credit Ratings on Liquidity and Collateral Obligations

IDACORP’s and Idaho Power’s access to capital markets, including the commercial paper market, and their respective financing costs in those markets, depend in part on their respective credit ratings. There have been no changes to IDACORP's or Idaho Power's ratings by ~~S&P~~Standard & Poor’s Ratings Services or Moody’s Investors Service from those included in the ~~2021~~2022 Annual Report. However, any rating can be revised upward or downward or withdrawn at any time by a rating agency if it decides that the circumstances warrant the change. In July 2022, Moody's Investors Service (Moody's) Long-Term Issuer rating for IDACORP was downgraded to Baa2 from Baa1, and Idaho Power's Long-Term Issuer rating was downgraded to Baa1 from A3. In addition, Moody's ratings for Idaho Power's First Mortgage Bonds and Senior Secured Debt were downgraded to A2 from A1. IDACORP and IPC's short-term ratings for commercial paper were affirmed at Prime-2 and the outlook for both companies were rated as stable. Following the Moody's credit ratings changes, the companies’ credit ratings remain investment grade and the companies do not believe the ratings changes will have a material impact on their liquidity nor access to debt capital. Moody’s credit ratings of Baa3 and above are considered to be investment grade, or prime, ratings.

Idaho Power maintains margin agreements relating to its wholesale commodity contracts that allow performance assurance collateral to be requested of and/or posted with certain counterparties. As of June 30, ~~2022,~~2023, Idaho Power had posted ~~$1.2~~$44 million of cash performance assurance collateral related to these contracts. Should Idaho Power experience a reduction in its credit rating on its unsecured debt to below investment grade, Idaho Power could be subject to requests by its wholesale counterparties to post additional performance assurance collateral, and counterparties to derivative instruments and other forward contracts could request immediate payment or demand immediate ongoing full daily collateralization on derivative instruments and contracts in net liability positions. Based upon Idaho Power’s current energy and fuel portfolio and market conditions as of June 30, ~~2022,~~2023, the amount of additional collateral that could be requested upon a downgrade to below investment grade is approximately ~~$14.5~~$19 million. To minimize capital requirements, Idaho Power actively monitors its portfolio exposure and the potential exposure to additional requests for performance assurance collateral through sensitivity analysis.

Capital Requirements

Idaho Power's ~~construction~~cash capital expenditures, excluding AFUDC, were ~~$187~~$265 million during the six months ended June 30, ~~2022.~~2023. The table below presents Idaho Power's estimated accrual-basis additions to ~~electric~~property, plant, and equipment for ~~2022~~2023 (including amounts incurred to-date) through ~~2026~~2027 (in millions of dollars). The amounts in the table exclude AFUDC but include net costs of removing assets from service that Idaho Power expects would be eligible to be included in rate base in future rate case proceedings. ~~However, given~~Given the uncertainty associated with the timing of infrastructure projects and associated expenditures, actual expenditures and ~~the~~their timing ~~of such expenditures~~ could deviate substantially from those set forth in the table. The capital expenditure table below assumes, among other projects, construction and ownership of a number of capacity resources identified in Idaho Power's RFP, 2021 IRP, and preliminary 2023 IRP modeling in order to safely and reliably serve the company's customers. The timing and amount of actual constructed projects and capital expenditures could be affected by Idaho Power’s ability to timely obtain labor or materials at

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reasonable costs, supply chain disruptions and delays, regulatory determinations, inflationary pressures, macroeconomic conditions, or other ~~issues.~~issues, including those described below.

2022 2023 2024-2026
Expected capital expenditures (excluding AFUDC) $500-$520 $690-$715 $1,450-$1,550


	2023	2024	2025-2027
Expected capital expenditures (excluding AFUDC)	$650-$700	$800-$850	$1,500-$1,700

Major Infrastructure Projects: Idaho Power is engaged in the development of a number of significant projects and has entered into arrangements with third parties concerning joint infrastructure development. The discussion below provides a summary of developments in certain of those projects since the discussion of these matters included in Part II, Item 7 - "MD&A - Capital Requirements" in the ~~2021~~2022 Annual Report. The discussion below should be read in conjunction with that report.

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Resource Additions to Address Projected Energy and Capacity Deficits: As noted previously, Idaho ~~Power believes that~~Power's existing and sustained growth in customers, load, and peak demand for electricity, along with transmission constraints, ~~will create~~has created the need for Idaho Power to acquire significant generation, transmission, and storage resources to meet energy and capacity needs over the next several years. While demand varies and is based on numerous factors, Idaho Power's 2021 IRP indicated Idaho Power could have a resource capacity deficit for peak needs of 101 MW in 2023, an additional 85 MW deficit in 2024, and an additional 125 MW deficit in 2025. To help meet peak needs in 2023 through 2025, Idaho Power ~~has~~ entered into or expects to enter into contracts to purchase, own, and operate ~~120~~approximately 300 MW of battery storage assets with expected useful lives of approximately 20 years, entered into a 20-year agreement to purchase the storage capacity from a 150-MW battery storage facility, and also entered into ~~a 20-year~~three power purchase ~~agreement signed~~agreements for the combined 340 MW output of planned third-party solar facilities with 20- to 25-year terms. As described in ~~February 2022 for~~“Regulatory Matters” of this MD&A, Idaho Power plans to sell the output of ~~a planned third-party 40~~two of these solar power purchase agreements totaling 240 MW ~~solar facility. In March 2022,~~exclusively to two large industrial customers under agreements modeled after Idaho Power filed an application with the IPUC requesting approval of a revised special contract for electric service between Idaho Power and its existing industrial customer Micron under which Micron would purchase from Idaho Power the energy generated by the solar facility.Power’s proposed Clean Energy Your Way program. To help address the additional capacity deficits projected for ~~2024 and 2025,~~2026 through 2027, Idaho Power has ~~been pursuing multiple options~~issued an RFP for additional resources. The capital requirements table above includes capital expenditures of more than $600 million from 2023 through 2027 for resource additions to address projected energy and ~~issued a request for proposal for resources~~capacity deficits in ~~December 2021.~~those years. Depending on factors such as RFP results, the timing of project in-service dates, ~~updated~~estimated load and resource balances and customer growth, the nature and quantity of resources owned versus acquired under power purchase agreements or similar agreements, and the outcome of regulatory proceedings, actual expenditures and their timing could deviate substantially from Idaho ~~Power expects it could invest over $400 million in capital expenditures from 2022 through 2025 for resource additions to help meet the projected capacity deficits noted above.~~Power's expected expenditures.

Boardman-to-Hemingway Transmission Line: The Boardman-to-Hemingway line, a ~~proposed~~planned 300-mile, high-voltage transmission project between a substation near Boardman, Oregon, and the Hemingway substation near Boise, Idaho, ~~would~~is expected to provide transmission service to meet future resource needs. ~~In January 2012,~~Material procurement and construction subcontract bid events are in progress and Idaho Power ~~entered into~~expects construction to begin in the second half of 2023. Given the status of ongoing activities and the construction period, Idaho Power expects the in-service date for the transmission line will be no earlier than 2026.

Until recently, Idaho Power had a joint funding agreement with PacifiCorp and ~~the Bonneville Power Administration (BPA)~~BPA to pursue permitting of the ~~project. The joint funding agreement provided that~~project, with Idaho ~~Power's~~Power having an approximate 21 percent interest, BPA having an approximate 24 percent interest, and PacifiCorp having an approximate 55 percent interest in the permitting phase of the project. In March 2023, BPA, PacifiCorp, and Idaho Power signed various agreements to facilitate certain asset transfers and other coordination efforts among the parties as the transmission line moves toward construction. In particular, an agreement between Idaho Power and BPA transferred BPA’s total interest in the project ~~would~~to Idaho Power, increasing Idaho Power's interest to approximately 45 percent, and provided that Idaho Power will deliver transmission service to BPA's customers across southern Idaho. The agreement also required BPA to make a $10 million security payment to Idaho Power. On Idaho Power's condensed consolidated balance sheet, the agreement increased construction work in progress by $31 million for the acquired permitting interest, cash and cash equivalents by $10 million for the additional security payment, and other non-current liabilities by $41 million for Idaho Power's obligation to pay for the permitting interest and to return the security deposit to BPA. Payments to BPA for the permitting interest are expected to be ~~approximately 21 percent.~~made over a 15-year period beginning 10 years after energization of the transmission line project, while the security deposit is due to be returned to BPA upon energization.

~~Approximately $137~~Idaho Power has spent approximately $169 million, including Idaho Power's AFUDC, ~~has been expended~~ on the Boardman-to-Hemingway project through June 30, ~~2022.~~2023. Pursuant to the terms of the joint funding arrangements, Idaho Power has received ~~$87~~ $107 million in reimbursement as of June 30, ~~2022,~~2023, from project co-participants for their share of ~~costs.~~costs (including $31 million related to BPA's share, which was transferred to Idaho Power in March 2023 as part of the agreement described above). As of the date of this report, no material co-participant reimbursements are outstanding. ~~Joint~~The remaining joint permitting ~~participants are~~participant is obligated to reimburse Idaho Power for ~~their~~its share of any future project permitting expenditures or agreed upon early construction expenditures incurred by Idaho Power under the terms of the joint funding agreement.

The permitting phase of the Boardman-to-Hemingway project iswas subject to federal review and approval by ~~the U.S. Bureau of Land Management (BLM), the U.S. Forest Service, the Department of the Navy, and certain other~~various federal agencies. The BLM issued its record of decision for the project in November 2017, approving a right-of-way grant for the project to cross approximately 86 miles of BLM-administered land. The U.S. Forest Service issued its record of decision in November 2018 authorizing the project to cross approximately seven miles of National Forest lands. In September 2019, the Department of the Navy issued its record of decision authorizing the project to cross approximately seven miles of Department of the Navy lands. In November 2019, third parties filed a lawsuit in the federal district court of Oregon challenging the BLM and U.S. Forest ServiceFederal agency records of decision ~~for the Boardman-to-Hemingway project on several grounds.~~ ~~In August 2021, the federal district court of Oregon dismissed the third-party~~have been received and all lawsuits challenging the ~~records of decision for the Boardman-to-Hemingway project and the third parties did not file to appeal that decision.~~

federal rights-of-way have been resolved. In the separate State of Oregon permitting process, the state's EFSC approved Idaho Power's site certificate on September 27, 2022. The Oregon Department of Energy subsequently issued a ~~Proposed Order in July 2020~~final order and site certificate. Three parties filed appeals to the Oregon Supreme Court asking that ~~recommends~~court to overturn EFSC's approval of the ~~project~~Boardman-to-Hemingway site certificate. On March 9, 2023, the Oregon Supreme Court affirmed the EFSC's final order approving Idaho Power's site certificate.

In June 2023, Idaho Power and PacifiCorp executed a construction funding agreement and filed it with the FERC. Idaho Power anticipates that the agreement will go into effect upon meeting the conditions precedent contained in the agreement relating to acceptance of the agreement by the FERC, receipt of the CPCNs for Boardman-to-Hemingway from Oregon and Idaho for Idaho Power and Idaho and Wyoming for PacifiCorp, and Idaho Power and PacifiCorp consenting to the state's Energy Facility Siting Council (EFSC). On May 31, 2022, at the conclusion of the administrative hearing, the hearing officer issued a proposed contested case order proposing Idaho Power be granted a site certificate to construct and operate the project in Oregon. The matter is now before the EFSC, which Idaho Power expects to make a final decision in the second half of 2022.

conditions contained within their respective CPCNs.

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As of June 2023, the ~~current joint funding agreement covers primarily permitting activities, which are nearing completion,~~IPUC, OPUC, and Wyoming Public Service Commission have granted, or made oral decisions approving, Idaho Power and ~~its co-participants have been exploring several scenarios of ownership, asset, and service arrangements aimed at maximizing~~PacifiCorp their respective CPCNs related to the ~~value~~construction of the project to each of the co-participants' customers. Under the current joint funding agreement, Idaho Power has an approximate 21 percent interest, BPA has an approximate 24 percent interest, and PacifiCorp has an approximate 55 percent interest in the permitting phase of theBoardman-to-Hemingway project. In January 2022, the participants executed a non-binding term sheet regarding the ownership structure that would be addressed through amended or new funding agreements for the future phases of the project. The term sheet contemplates that Idaho Power would acquire BPA's ownership interest, which would increase Idaho Power's interest to approximately 45 percent, and Idaho Power would deliver transmission service to BPA's customers across Southern Idaho.

Total cost estimates for the project are trending toward the upper end of Idaho Power's estimated cost range of between ~~$1.0~~$1.1 billion and ~~$1.2~~$1.3 billion, including Idaho Power's AFUDC. The capital requirements table above includes approximately ~~$380~~$430 million of Idaho Power's share of estimated costs (excluding AFUDC) related to the remaining permitting phase, design, material procurement, and construction phases of the project. The preliminary estimates of construction costs could ~~significantly~~ change as the construction timeline nears and as the project participants obtain more detailed information on construction and material costs.

~~In July 2021, Idaho Power awarded contracts for detailed design, geotechnical investigation, land surveying, and right-of-way option acquisition; and that work commenced in the t~~hird quarter of 2021. In April 2022, Idaho Power awarded a contract for constructability consulting services. Idaho Power's 2021 IRP included the Boardman-to-Hemingway transmission line in its resource capacity plans for 2026. ~~Given the status of ongoing permitting activities and the construction period, Idaho Power expects the in-service date for the transmission line will be no earlier than 2026.~~

Gateway West Transmission Line: Idaho Power and PacifiCorp are pursuing the joint development of the Gateway West project, a high-voltage transmission lines project between a substation located near Douglas, Wyoming, and the Hemingway substation located near Boise, Idaho. In ~~January~~ 2012, Idaho Power and PacifiCorp entered a joint funding agreement for permitting of the project. Idaho Power has expended approximately ~~$50~~$57 million, including Idaho Power's AFUDC, for its share of the permitting phase of the project through June 30, ~~2022.~~2023. As of the date of this report, Idaho Power estimates the total cost for its share of the project (including both permitting and construction) to be trending toward the upper end of the cost range between ~~$250~~$300 million and ~~$450~~$500 million, including AFUDC. The capital requirements table above includes approximately $40 million of Idaho Power's ~~estimated~~ share of ~~ongoing expenditures~~estimated costs (excluding AFUDC) for the permitting phase of the project ~~(excluding AFUDC) is included in the capital requirements table above. Idaho Power's share of potential~~and early construction costs, ~~are excluded from the capital requirements table above because the timing of~~based on Idaho Power's current estimate that it may commence construction of ~~Idaho Power's portion of the project is uncertain.~~applicable segments during that time period.

The permitting phase of the Gateway West project was subject to review and approval of the ~~BLM.~~U.S. Bureau of Land Management (BLM). The BLM has published its records of decision for all segments of the transmission line. In late 2020, PacifiCorp ~~recently constructed~~completed construction and commissioned a 140-mile segment of ~~their~~its portion of the project in Wyoming. In March 2023, PacifiCorp initiated the pre-construction phase of 620 miles of 500-kV transmission line from the Populus substation near Downey, Idaho, to the Hemingway substation near Melba, Idaho. Idaho Power and PacifiCorp continue to coordinate the timing of next steps to best meet customer and system needs.

Defined Benefit Pension Plan Contributions

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in ~~2022~~2023, and during the six months ended June 30, ~~2022,~~2023, Idaho Power made a $10 million contribution. ~~In July 2022,~~ Idaho Power ~~made~~is considering contributing up to an additional ~~$10~~$30 million ~~contribution~~ to ~~the defined benefit~~its pension plan during 2023 in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions, ~~and~~as well as to mitigate the cost of being in an underfunded position. ~~Idaho Power is considering contributing up to an additional $20 million to its defined benefit pension plan during 2022.~~ The primary impact of pension contributions is on the timing of cash flows, as the timing of cost recovery lags behind contributions.

Contractual Obligations

IDACORP’s and Idaho Power’s contractual cash obligations ~~as of~~have not materially changed during the six months ended June 30, ~~2022, include long-term debt, interest payments, purchase obligations, pension~~2023, except as disclosed in Note 5 – “Long-Term Debt” and ~~post-retirement benefit plans, and other long-term liabilities specific to IDACORP, most of which are discussed throughout this MD&A. Refer to~~ Note 8 – “Commitments” to the condensed consolidated financial statements included in this ~~report for~~report.

Dividends

The amount and timing of dividends paid on IDACORP’s common stock are within the discretion of IDACORP’s board of directors. IDACORP's board of directors reviews the dividend rate periodically to determine its appropriateness in light of IDACORP’s current and long-term financial position and results of operations, capital requirements, rating agency considerations, contractual and regulatory restrictions, legislative and regulatory developments affecting the electric utility industry in general and Idaho Power in particular, competitive conditions, and any other factors the board of directors deems relevant. The ability of IDACORP to pay dividends on its common stock is generally dependent upon dividends paid to it by its subsidiaries, primarily Idaho Power.

For additional information relating to ~~contractual obligations~~IDACORP and Idaho Power dividends, including restrictions on IDACORP’s and Idaho Power’s payment of dividends, see Note 6 - “Common Stock” to the ~~companies.~~condensed consolidated financial statements included in this report.

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Off-Balance Sheet Arrangements

IDACORP's and Idaho Power's off-balance sheet arrangements have not changed materially from those reported in MD&A in the ~~2021~~2022 Annual Report.

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REGULATORY MATTERS

Introduction

Idaho Power is under the jurisdiction (as to rates, service, accounting, and other general matters of utility operation) of the IPUC, the OPUC, and the FERC. The IPUC and OPUC determine the rates that Idaho Power is authorized to charge to its retail customers. Idaho Power is also under the regulatory jurisdiction of the IPUC, the OPUC, and the ~~WPSC~~Wyoming Public Service Commission as to the issuance of debt and equity securities. As a public utility under the Federal Power Act, Idaho Power has authority to charge market-based rates for wholesale energy sales under its FERC tariff and to provide transmission services under its OATT. Additionally, the FERC has jurisdiction over Idaho Power's sales of transmission capacity and wholesale electricity, hydropower project relicensing, and system reliability, among other items.

Idaho Power develops its regulatory filings taking into consideration short-term and long-term needs for rate relief and several other factors that can affect the structure and timing of those filings. These factors include in-service dates of major capital investments, the timing and magnitude of changes in major revenue and expense items, and customer growth rates, as well as other factors. Idaho Power's most recent general rate cases in Idaho and Oregon were filed during 2011, and in 2012, large single-issue rate cases for the Langley Gulch power plant resulted in the resetting of base rates in both Idaho and Oregon. Idaho Power also reset its base-rate power supply expenses in the Idaho jurisdiction for purposes of updating the collection of costs through retail rates in 2014 but without a resulting net increase in rates. The IPUC and OPUC have also approved base rate changes in single-issue cases subsequent to 2014.

Between general rate cases, Idaho Power relies upon customer growth, a FCA mechanism, power cost adjustment mechanisms, tariff riders, and other mechanisms to mitigate the impact of regulatory lag, which refers to the period of time between making an investment or incurring an expense and recovering that investment or expense and earning a return. Management's regulatory focus in recent years has been largely on regulatory settlement stipulations and the design of rate mechanisms. With Idaho Power’s current and anticipated significant infrastructure investments, including those that are intended to help meet projected near-term capacity deficits, Idaho Power’s evaluations indicate that the appropriate time to file general rate cases in both Idaho and Oregon is approaching. The resulting expected increase in rate-base eligible assets as these projects are placed into service, along with the significant amounts of capital expenditures Idaho Power ~~has made since its last~~filed a general rate case ~~filed~~ in ~~2011, will increase and potentially accelerate~~ Idaho ~~Power’s need to file~~on June 1, 2023, with a general rate ~~cases.~~case filing in Oregon likely to follow in late 2023 or 2024. Refer to Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report for additional information regarding the Idaho general rate case filing.

The outcomes of significant proceedings are described in part in this report and further in the ~~2021~~2022 Annual Report. In addition to the discussion below, which includes notable regulatory developments since the discussion of these matters in the ~~2021~~2022 Annual Report, refer to Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report for additional information relating to Idaho Power's regulatory matters and recent regulatory filings and orders.

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Notable Retail Rate Changes

During ~~2022,~~2023, Idaho Power received orders authorizing the rate changes summarized in the table below.

Description

Status

Estimated ~~Annual~~ Rate Impact(1)

Notes

~~Jim Bridger plant accelerated recovery~~

~~New base rates became effective June 1, 2022~~

~~$18.8 million increase effective June 1, 2022~~

The IPUC approved Idaho Power’s amended application requesting authorization to recover costs associated with its plan to cease participation in coal-fired operations at the Jim Bridger plant by 2028, as described in more detail below.

Power Cost Adjustment Mechanism - Idaho

New PCA rate became effective June 1, ~~2022~~2023

$~~94.9~~105.1 million PCA increase for the period from June 1, ~~2022,~~2023, to May 31, ~~2023~~2024

The income statement impact of revenue changes associated with the Idaho PCA mechanism is largely offset by associated increases and decreases in actual power supply costs and amortization of deferred power supply costs. The rate increase reflects ~~a forecasted reduction in low-cost hydropower generation as well as~~ higher costs associated with market energy ~~prices~~ and natural gas ~~prices.~~prices, combined with limited coal supply. The ~~filing also reflects $0.6~~IPUC order approving the PCA increase defers collection of $95.1 million of ~~2021 earnings~~deferred PCA costs to ~~be shared with customers under~~ the ~~May 2018 Idaho Tax Reform Settlement Stipulation described below.~~subsequent annual PCA collection period.

Fixed Cost Adjustment Mechanism - Idaho

New FCA rate became effective June 1, ~~2022~~2023

$~~3.1~~10.1 million FCA decrease for the period from June 1, ~~2022,~~2023, to
May 31, ~~2023~~2024

The FCA is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by partially separating (or decoupling) the recovery of fixed costs from the volumetric kilowatt-hour (kWh) charge and instead linking it to a set amount per customer.

Annual Power Cost Update - Oregon

New APCU rate became effective June 1, 2023

$7.7 million APCU increase for the period from June 1, 2023, to May 31, 2024

The rate increase reflects continued high natural gas prices, combined with limited coal generation and increased forward market electric prices.

(1) The annual amount collected in rates is typically not recovered on a straight-line basis (i.e., 1/12th per month), and is instead recovered in proportion to retail sales volumes.

Idaho Earnings Support and Sharing from Idaho Settlement Stipulation

A May 2018 Idaho settlement stipulation related to tax reform (May 2018 Idaho Tax Reform Settlement Stipulation) is described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the ~~2021~~2022 Annual Report. IDACORP and Idaho Power believe that the terms allowing additional amortization of ADITC in the settlement stipulations provide the companies with a greater degree of earnings stability than would be possible without the terms of the stipulations in effect. Based on its estimate of full-year ~~2022~~2023 Idaho ROE, in the ~~second quarter of 2022,~~three and six months ended June 30, 2023, Idaho Power recorded no$3.8 million and $7.5 million, respectively, in additional ADITC amortization ~~or provision against current revenues for sharing of earnings with customers~~ under the May 2018 Idaho Tax Reform Settlement Stipulation. Accordingly, at June 30, ~~2022, the full $45~~2023, $37.5 million of additional ADITC remains available for future use. Idaho Power ~~also~~ recorded no additional ADITC amortization or provision against revenues for sharing of earnings with customers during ~~the second quarter of 2021, based on its then-current estimate of full-year 2021 Idaho ROE.~~2022.

Change in Deferred (Accrued) Net Power Supply Costs and the Power Cost Adjustment Mechanisms

Deferred (accrued) power supply costs represent certain differences between Idaho Power's actual net power supply costs and the costs included in its retail rates, the latter being based on annual forecasts of power supply costs. Deferred (accrued) power supply costs are recorded on the balance sheets for future recovery or refund through customer rates.

Idaho Power's power cost adjustment mechanisms in its Idaho and Oregon jurisdictions address the volatility of power supply costs and provide for annual adjustments to the rates charged to retail customers. The power cost adjustment mechanisms and associated financial impacts are described in "Results of Operations" in this MD&A and in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. With the exception of power supply expenses incurred under PURPA and certain demand response program costs that are passed through to customers substantially in full, the Idaho PCA mechanism allows Idaho Power to pass through to customers 95 percent of the differences in actual net power supply expenses as compared with base net power supply expenses, whether positive or negative. Thus, the primary financial statement impact of power supply cost deferrals or accruals is that the timing of when cash is paid out for power supply expenses differs from when those costs are recovered from customers, impacting operating cash flows from year to year.

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The following table summarizes the change in deferred (accrued) net power supply costs during the six months ended June 30, ~~2022~~2023 (in millions).

Idaho Oregon Total
Deferred (accrued) net power supply costs at December 31, 2021 $ 33.8 $ (0.3) $ 33.5
Current period net power supply costs accrued (3.4) — (3.4)
Revenue sharing (0.6) — (0.6)
Prior amounts refunded through rates 3.4 0.1 3.5
SO2 allowance and renewable energy certificate sales
(5.2) (0.2) (5.4)
Interest and other 1.5 (0.1) 1.4
Deferred (accrued) net power supply costs at June 30, 2022 $ 29.5 $ (0.5) $ 29.0


	Idaho		Oregon		Total
Deferred net power supply costs at December 31, 2022	$	128.7	$	0.6	$	129.3
Current period net power supply costs deferred (accrued)	25.3		(0.3)		25.0

Prior amounts collected through rates	(23.3)		—		(23.3)
SO2 allowance and renewable energy certificate net sales	(7.6)		(0.3)		(7.9)
Interest and other	2.9		—		2.9
Deferred net power supply costs at June 30, 2023	$	126.0	$	—	$	126.0

Open Access Transmission Tariff Draft Posting

Idaho Power uses a formula rate for transmission service provided under its OATT, which ~~allows~~provides that transmission rates towill be updated annually based primarily on financial and operational data Idaho Power files with the FERC. The existing OATT rate in effect from October 1, ~~2021,~~2022, to September 30, ~~2022,~~2023, is ~~$31.19~~$31.42 per ~~kW-year~~"kW-year" based on a net annual transmission revenue requirement of ~~$127.3~~$132.7 million. In ~~June 2022,~~May 2023, Idaho Power publicly posted its ~~2022~~2023 draft transmission rate, reflecting a transmission rate of ~~$31.42~~$31.13 per "kW-year," to be effective for the period from October 1, ~~2022,~~2023, to September 30, ~~2023.~~2024. A "kW-year" is a unit of electrical capacity equivalent to 1 kilowatt of power used for 8,760 hours. Idaho Power's draft rate was based on a net annual transmission revenue requirement of ~~$132.7~~$137.4 million.

Boardman-to-Hemingway Transmission Line Certificates of Public Convenience and Necessity

In June 2023, the IPUC and OPUC both issued orders granting Idaho Power's applications for certificates of public convenience and necessity authorizing construction of the Boardman-to-Hemingway 500-kV transmission line. The ~~increase~~Boardman-to-Hemingway project is described in more detail in the ~~draft OATT rate is largely attributable to increased transmission plant in service.~~"Liquidity and Capital Resources" section of this MD&A.

Oregon Resource Procurement Filing

~~In December 2021, Idaho Power filed an application with the OPUC requesting a waiver~~The State of ~~Oregon's~~Oregon has competitive bidding rules ~~for Idaho Power's~~regarding a public utility's procurement of resources to fill near-term capacity deficits. Specifically, Idaho Power requested that the OPUC issue an order waiving Idaho Power’s obligation to comply with the competitive bidding rules for its proposed resource procurement in favor of a modified competitive process and authorizing Idaho Power to move forward expeditiously with resource procurement to meet identified resource needs in 2023, 2024, and 2025. In March 2022, the OPUC issued an order denying Idaho Power's request to waive t~~he competitive bidding rules.~~. However, as allowed by the OPUC in certain cases, Idaho Power is pursuing an exception for 2023 resource needs, and plans to pursue additional exceptions to the competitive bidding rules for certain projects to meet the identified resource needs in 2024 and 2025.

~~Filing for Certificate of Public Convenience~~In July 2023, following review by an independent evaluator appointed by the OPUC, OPUC staff, and ~~Necessity for Battery Storage Projects~~

~~In April 2022, Idaho Power filed an application with~~other intervenors, the IPUC requesting that the IPUC issue a Certificate of Public Convenience and Necessity (CPCN) authorizing Idaho Power to install, own, and operate two battery storage facilities. The 120 MW combined capacity of the two projects is planned to help meet peak energy needs in the summer of 2023 and beyond. The CPCN is intended to allow the IPUC to review the need for the project prior to Idaho Power incurring the bulk of the associated expenses. As of the date of this report, the IPUC's decision in this matter is pending.

~~Customer-Owned Generation Filing~~

Customer-owned generation allows customers to install solar panels or other on-site energy-generating resources and connect them to Idaho Power’s grid. If a customer requires more energy than its system generates, it uses energy supplied by Idaho Power’s grid and infrastructure. If a customer's system generates more energy than the customer uses, the energy is transferred to the grid and Idaho Power applies a corresponding kilowatt-hour credit to the customer’s bill. In May 2018, the IPUCOPUC issued an order ~~authorizing the creation of two new customer classes~~approving Idaho Power's final RFP to procure resources for ~~residential~~its anticipated energy and small commercial customers who install their own on-site generation, with no change to pricing or compensation. Since October 2018, Idaho Power has initiated several cases with the IPUC related to studying the costscapacity needs in 2026 and benefits of customer-owned generation on Idaho Power’s system, and exploring whether, and to what extent, there should be modifications to the customer-owned generation pricing structure for residential and small general service customers, and large commercial, industrial, and irrigation customers (CI&I). The IPUC issued orders in December 2019 and February 2020 directing Idaho Power to (1) complete additional studies related to the costs and benefits of customer generation before changes to the compensation structure are implemented, and (2) continue to allow residential and small commercial customers with on-site generation installed prior to December 20, 2019, to be subject to the compensation and billing structure in place on that date until December 20, 2045. In December 2020, the IPUC issued an order

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~~establishing a 25-year grandfathering term for CI&I customers, similar to the terms approved for the residential and small commercial customer classes.~~

In June 2021, Idaho Power filed an application requesting that the IPUC initiate the multi-phase process for a comprehensive study of the costs and benefits of on-site generation as directed by previous IPUC orders. In December 2021, the IPUC issued an order requiring Idaho Power to complete the comprehensive study on the costs and benefits of on-site generation based on the IPUC’s study framework findings and conclusions, and requiring that Idaho Power complete the study in 2022 as soon as feasible. In June 2022, Idaho Power filed the comprehensive study with a proposed schedule that would allow the IPUC to issue a determination regarding the future structure of the service offering by the end of 2022, with implementation no earlier than June 2023.2027.

Jim Bridger Power Plant Base Rate ~~Base~~ Adjustment and Recovery

In June 2022, the IPUC issued ~~an order~~the Bridger Order approving, with modifications, Idaho Power’s amended application requesting authorization to ~~(a)~~(1) accelerate depreciation for the Jim Bridger plant, to allow the coal-related plant assets to be fully depreciated and recovered by December 31, 2030, ~~(b)~~(2) establish a balancing account to track the incremental costs, benefits, and required regulatory accounting associated with ceasing participation in coal-fired operations at the Jim Bridger plant, and ~~(c) adjust~~(3) increase customer rates related to ~~recover~~ the associated incremental annual levelized revenue ~~requirement (Bridger Order).The~~requirement. The Bridger Order and associated accounting are described in Note 3 – “Regulatory Matters” to the condensed consolidated financial statements included in this report. ~~As a result of the Bridger Order, Idaho Power recorded the deferral of certain depreciation expense in the second quarter of 2022.~~ Idaho Power plans to cease participation in all coal-related operations at the Jim Bridger plant by 2028. Idaho Power expects the Bridger Order to increase operating revenues, net depreciation expense, and income tax expense in future periods, and estimates the impacts of the order will increase after-tax net income by approximately $10 million in 2023. Idaho Power expects the ongoing annual benefit to net income from the Bridger Order to decline each year through 2030, primarily due to the annual decline in Jim Bridger plant coal-related rate base, which Idaho Power expects to be fully depreciated by December 31, 2030.

Wildfire Mitigation Cost Deferral

In June 2021, the IPUC authorized Idaho Power to defer for future amortization incremental O&M and depreciation expense of certain capital investments necessary to implement the company's WMP. The IPUC also authorized Idaho Power to record these deferred expenses as a regulatory asset until the company can request amortization of the deferred costs in a future IPUC proceeding, at which time the IPUC will have the opportunity to review actual costs and determine the amount of prudently incurred costs that Idaho Power can recover through retail rates. In its 2021 application with the IPUC, Idaho Power ~~projects~~projected spending approximately $47 million in incremental wildfire mitigation-related O&M and roughly $35 million in wildfire mitigation system-hardening incremental capital ~~incremental~~ expenditures over ~~the next~~a five ~~years.~~year period. The IPUC authorized a deferral period of five years, or until rates go into effect after Idaho Power's next general rate case, whichever is first. As of June 30, ~~2022,~~2023, Idaho Power’s deferral of Idaho-jurisdiction costs related to the WMP was ~~$14.8~~$39.5 million.

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~~Industrial Customer Dedicated Renewable Resource~~

During the 2021 and 2022 wildfire seasons, Idaho Power identified needs for expanded mitigation measures by gaining additional insights and knowledge on wildfires and wildfire mitigation activities. In ~~March~~October 2022, Idaho Power filed an ~~application~~updated WMP with the IPUC along with an application requesting ~~approval~~authorization to defer an estimated $16 million of ~~a revised special contract for electric service~~newly identified incremental costs expected to be incurred between 2022 and 2025 associated with expanded wildfire mitigation efforts. In March 2023, the IPUC approved Idaho ~~Power~~Power's updated WMP and ~~its existing industrial customer, Micron. The application included~~request to defer additional incremental costs.

Large Customer Rate Proceedings

Brisbie, LLC Data Center: In April 2023, the IPUC approved an arrangement, modeled after the Clean Energy Your Way program as described in the 2022 Annual Report in Part II, Item 7 - "Regulatory Matters," under which ~~Micron~~a new large load customer, Brisbie, LLC (Brisbie), a wholly-owned subsidiary of Meta Platforms, Inc., would ~~be the purchaser~~purchase from Idaho Power ~~of the~~ energy for a new 960,000 square-foot enterprise data center. The energy to be purchased by Brisbie is anticipated to be generated by a to-be-constructed ~~40 MW~~200-MW solar facility pursuant to a ~~20-year~~long-term power purchase agreement between Idaho Power and a third party. The solar facility is scheduled to begin operating as early as ~~June 2023.~~March 2025.

In May 2023, the IPUC issued an order approving, with modifications, a special contract for electric service for Brisbie for the new data center. Idaho regulations require any utility customer with an average load exceeding 20 MW to enter into a special contract with its electric provider. Brisbie, in addition to its large load service requirements in excess of 20 MW, has a sustainability objective to support 100 percent of its operations with new renewable resources. Under the special contract, Idaho Power ~~also requested~~expects to procure enough renewable resources to provide Brisbie with 100 percent renewable energy on an annual basis for Brisbie’s facility. The IPUC approval of the special contract requires Idaho Power to file a modified energy services agreement and rate schedule, which Idaho Power plans to file by August 9, 2023.

Micron Dedicated Renewable Resource: In August 2022, the IPUC issued an order approving, with modifications, Idaho Power's application for a revised special contract for electric service between Idaho Power and Micron. The application was modeled after the Clean Energy Your Way program as described in the ~~application~~2022 Annual Report in Part II, Item 7 - "Regulatory Matters," and included an arrangement under which Micron would purchase from Idaho Power energy generated by a to-be-constructed 40-MW solar facility pursuant to a 20-year power purchase agreement between Idaho Power and a third party. The solar facility began operating in May 2023.

In April 2023, the IPUC issued an order approving Idaho Power's compliance filing of revised electric service rates for Micron that include new energy rates that incorporate the solar generation and compensation for capacity value and excess renewable energy generation. ~~The application is modeled after a separate case pending before the IPUC requesting that~~

Lamb Weston, Inc. Special Contract: In May 2023, Idaho Power ~~be permitted to expand~~filed an application for approval of a special contract for electric service for an existing large load customer, ~~clean energy offerings through a new "Clean Energy Your Way~~" program, which would provide certain large customers the opportunity to purchase the output of renewable energy facilities, as described in the 2021 Annual Report in Part II, Item 7 - "Regulatory Matters." In early August, the IPUC issued an order approving Idaho Power’s application, with modifications, whichLamb Weston, Inc. (Lamb Weston). Idaho Power ~~is evaluating as~~anticipates Lamb Weston's large load service requirements to exceed 20 MW and Idaho regulations require any utility customer with an average load exceeding 20 MW to enter into a special contract with its electric provider. As of the date of this ~~report.~~report, the IPUC's decision in this matter is pending.

~~Large Customer Rate Proceedings - Speculative High-Density Load~~Western Resource Adequacy Program

In ~~June 2022,~~March 2023, Idaho Power filed an application with the IPUC ~~approved~~requesting that the IPUC issue an order acknowledging the potential for long-term cost savings associated with Idaho Power's ~~application~~participation in the Western Resource Adequacy Program (WRAP), and allowing the company to ~~create~~recover WRAP-associated costs in a ~~new customer class that would be applicable to commercial~~future rate proceeding. The WRAP is a regional reliability and ~~industrial cryptocurrency mining operations, or any other speculative high-density load customers~~compliance program being developed in western North America with the intent of ~~less than 20 MW.~~providing a region-wide approach for assessing and addressing resource adequacy and reliability. Idaho Power ~~has received approximately 2,000 MW~~anticipates that by participating in the WRAP it can avoid paying higher prices for energy in the wholesale markets, which savings would largely be provided to customers through Idaho Power's power cost adjustment mechanisms. In addition to the potential cost savings, Idaho Power anticipates its participation in the WRAP to provide the company with insight into regional resource adequacy and the ability to procure energy and capacity in times of ~~potential~~extreme need. As of the date of this report, the IPUC's determination in this matter is pending.

Customer-Owned Generation Filing

Customer-owned generation enables customers to install solar panels or other on-site energy-generating resources and connect them to Idaho Power’s grid. If a customer ~~interest from this industry~~requires more energy than its system generates, it uses energy supplied by Idaho Power’s grid and ~~believes new~~infrastructure. If a customer's system ~~resources may be necessary to serve this speculative~~generates more energy than the customer ~~load, which could create a financial risk for Idaho Power~~uses, the energy is transferred

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~~and its customers if~~to the ~~underlying economics of cryptocurrency mining change.~~grid and Idaho Power ~~believes~~applies a corresponding kWh credit to the customer’s bill. In May 2018, the IPUC issued an order authorizing the creation of two new customer classes for residential and small commercial customers who install their own on-site generation, with no change to pricing or compensation. Idaho Power has initiated several cases with the IPUC related to studying the costs and benefits of customer-owned generation on Idaho Power’s system, and exploring potential modifications to the customer-owned generation pricing structure. In December 2019 and February 2020, the IPUC issued orders directing Idaho Power to (1) complete additional studies related to the costs and benefits of customer generation before changes to the compensation structure are implemented, and (2) continue to allow residential and small commercial customers with on-site generation installed prior to December 20, 2019, to be subject to the compensation and billing structure in place on that date until December 20, 2045. In December 2020, the ~~financial~~IPUC issued an order establishing a 25-year grandfathering term for large commercial, industrial, and ~~system risks of speculative high-density load could be mitigated through rate design~~irrigation customers, similar to the terms approved for ~~this~~the residential and small commercial customer ~~class, which prices energy at a marginal rate, and through a requirement that speculative high-density load customers be interruptible at Idaho Power's discretion from~~classes.

In June ~~15 through September 15, Idaho Power's summer peak season. On July 6,~~ 2022, ~~a prospective cryptocurrency mining customer of~~as directed by the IPUC, Idaho Power filed a ~~petition for late intervention~~comprehensive study on the costs and ~~reconsideration~~benefits of on-site generation based on the ~~IPUC's approval~~IPUC’s study framework findings and conclusions, and in December 2022, the IPUC issued an order that acknowledged the company's study and directed Idaho Power to file a new case requesting to implement changes to the structure and design of ~~the new speculative high-density load customer class.~~its on-site generation program. In May 2023, Idaho Power filed ~~an answer~~a new case as directed by the IPUC, requesting the IPUC ~~deny both~~to implement changes for non-grandfathered customers starting January 1, 2024, including: 1) a change from net monthly to real-time net billing, which would better measure customers’ actual reliance on the ~~request~~grid; 2) a change in the excess exported energy credit from a kWh credit ranging in value of 5 to 12 cents, depending on the customer class, to a time-differentiated financial bill credit ranging from approximately 5 to 20 cents per kWh that would be updated annually; and 3) a modification to the eligibility cap for ~~intervention~~large commercial, industrial, and ~~reconsideration and, as~~irrigation customers. As of the date of this report, ~~a decision on~~ the ~~petition~~IPUC's determination in this matter is ~~pending.~~pending.

Renewable and Other Energy Contracts

Idaho Power has contracts for the purchase of electricity produced by third-party owned generation facilities, most of which produce energy with the use of renewable generation sources such as wind, solar, biomass, small hydropower, and geothermal. The majority of these contracts are entered into as mandatory purchases under PURPA. As of June 30, ~~2022,~~2023, Idaho Power had contracts to purchase energy from 129 online PURPA projects. An additional ~~three~~five contracts are with online non-PURPA projects, including the Elkhorn Valley wind project with a 101-MW nameplate capacity, the Jackpot Solar project with a 120-MW nameplate capacity, and the Black Mesa solar project with a 40-MW nameplate capacity.

The following table sets forth, as of June 30, ~~2022,~~2023, the resource type and nameplate capacity of Idaho Power's signed agreements for power purchases from PURPA and non-PURPA generating facilities. These agreements have original contract terms ranging from one to 35 years.


Resource Type	Resource Type	On-line (MW)	Under Contract but not yet On-line (MW)	Total Projects under Contract (MW)	Resource Type	Online (MW)	Under Contract but not yet Online (MW)	Total Projects under Contract (MW)
PURPA:	PURPA:				PURPA:
Wind	Wind	627	—	627	Wind	625	—	625
Solar	Solar	316	74	390	Solar	316	74	390
Hydropower	Hydropower	150	1	151	Hydropower	150	1	151
Other	Other	44	—	44	Other	44	—	44
Total	Total	1,137	75	1,212	Total	1,135	75	1,210
Non-PURPA:	Non-PURPA:				Non-PURPA:
Wind	Wind	101	—	101	Wind	101	—	101
Geothermal	Geothermal	35	—	35	Geothermal	35	—	35
Solar	Solar	—	160	160	Solar	160	300	460
Total	Total	136	160	296	Total	296	300	596

The PURPA-qualifying facility projects not yet ~~on-line~~online include one ~~PURPA-qualifying facility~~ hydropower project that is scheduled to be ~~on-line~~online in ~~2022, two~~2023, and three PURPA-qualifying facility solar projects ~~scheduled~~expected to be ~~on-line~~online in ~~2023, and one PURPA-qualifying facility solar project scheduled to be on-line in~~ 2024. ~~One~~ Two non-PURPA solar ~~project is~~projects, for 100 MW and 200 MW, are scheduled to be online in ~~2022~~2024 and ~~another~~2025, respectively. In February 2023, Idaho Power filed an application with the IPUC requesting an order approving the agreement with the 100 MW solar project, and granting Idaho Power a

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certificate of public convenience and necessity to acquire a total of 72 MW of new dispatchable energy storage to meet identified capacity deficiencies in ~~2023.~~

In July 2020, the FERC issued Order No. 872, which could affect how states determine PURPA project avoided cost rates for purchases of power generated from PURPA qualifying facilities (QF), which facilities are eligible for QF status, whether and when certain QFs can enter into purchase agreements with utilities, and how parties can contest the eligibility of a generation facility seeking QF status.2024. As of the date of this report, the IPUC's determination in this matter is pending.

In April 2023, Idaho Power ~~is unable~~entered into an agreement, pending regulatory approval, with a 150-MW battery storage facility, scheduled to ~~determine~~be online in June 2025. Under the ~~impact~~agreement, the facility would provide 150 MW of ~~these potential changes~~capacity on Idaho Power’s system for a period of 20 years, and Idaho Power would have the ~~company's future obligations~~exclusive right to dispatch and use the charging and discharging energy in exchange for ~~PURPA power purchase contracts. Further action by~~a monthly payment.In May 2023, Idaho Power filed an application with the ~~state~~IPUC requesting an order approving the agreement and acknowledging the lease accounting necessary to facilitate the transaction, and that the resulting expenses are prudently incurred for ratemaking purposes. As part of that same application, Idaho Power requested the IPUC issue an order granting Idaho Power a certificate of public ~~utility commissions is required~~convenience and necessity to ~~implement many~~acquire a total of 101 MW of new dispatchable energy storage to meet identified capacity deficiencies in both 2024 and 2025. As of the ~~changes. Substantially all PURPA power purchase costs are recovered through base rates and Idaho Power's power cost adjustment mechanisms.~~date of this report, the IPUC's decision in these matters is pending.

Relicensing of Hydropower Projects

HCC Relicensing: In connection with Idaho Power's major efforts to relicense the HCC, Idaho Power's largest hydropower complex, ~~and a major relicensing effort,~~ as described in more detail in the ~~2021~~2022 Annual Report in Part II, Item 7 - "Regulatory Matters," Idaho Power filed water quality certification applications, required under Section 401 of the Clean Water Act (CWA), with the states of Idaho and Oregon requesting that each state certify that any discharges from the project comply with applicable state water quality standards. Idaho Power continues to work with the states on measures that will provide reasonable assurance that discharges from the HCC will adequately address applicable water quality standards.

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In April 2019, the states of Idaho and Oregon, along with Idaho Power, reached a settlement pertaining to the CWA Section 401 certification that requires Idaho Power, among other measures, to increase the number of Chinook salmon it releases each year through expanded hatchery production. Additionally, Idaho Power is required to fund a total of $12 million of research and water quality improvements in the HCC over a 20-year period following the issuance of the license. Idaho Power estimates that the combined cost of the mandated water quality improvements and expanded hatchery production is $20 million in aggregate over the first 20 years of the new license term. In May 2019, Oregon and Idaho issued final CWA Section 401 certifications. These certifications have been submitted to the FERC ~~as part of the relicensing process. In~~in July 2019, three third parties filed lawsuits against the Oregon Department of Environmental Quality in Oregon state court challenging the Oregon CWA Section 401 certification based on fish passage, water temperature, and mercury issues associated with the Snake River and the HCC. Two of the lawsuits were consolidated, and Idaho Power intervened in that lawsuit and the parties reached a settlement. The court dismissed the third challenge to the Oregon CWA 401 certification with prejudice. No parties challenged the Idaho CWA 401 certification. In December 2019, Idaho Power filed an Offer of Settlement with the FERC requesting specific language be included in the new HCC license based upon the settlement among Idaho, Oregon, and Idaho Power. During the first quarter of 2020 ~~the FERC received several comments opposing the Offer of Settlement, and its decision relating to the Offer of Settlement is pending as of the date of this report.~~

~~In July 2020, Idaho Power submitted to the FERC~~ its supplement to the final license ~~application that~~application. The supplement incorporated the settlement agreement reached between Idaho and Oregon on the Clean Water Act (CWA) Section 401 certifications, which precipitated the states issuing final CWA Section 401 certifications in May 2019. The states of Idaho and ~~provided~~Oregon also submitted the CWA Section 401 certifications to the FERC as part of the relicensing process. The supplement included feedback on proposed ~~modification~~modifications of the 2007 final environmental impact statement (EIS) for the ~~HCC. The July 2020 filing also contained~~HCC, as well as an updated cost analysis of the HCC and a request ~~for~~that the FERC to issue a 50-year license and initiate a supplemental National Environmental Policy Act (NEPA) process at the FERC. Idaho Power prepared draft biological assessments in consultation with the U.S. Fish and Wildlife Service (USFWS) and the National Marine Fisheries Service (NMFS) and filed those with the FERC in October 2020. The draft biological assessments provide information to the USFWS and the NMFS that is necessary to issue their biological opinion as required under the Endangered Species Act (ESA). InSince December 2020, ~~FERC staff issued six~~Idaho Power has responded to sixteen additional information requests ~~(AIRs) from Idaho Power~~issued by the FERC staff to ~~help with~~aid in the analysis and baseline for the project moving forward. Idaho Power has filed responses to all six of the AIRs with the FERC. Subsequently, in September 2021 FERC issued ten additional AIRs to clarify the cost of the proposed mitigation measures. FERC's analysis.

In June 2022, the FERC issued a ~~notice~~Notice of ~~intent~~Intent (NOI) to prepare a ~~draft and final~~ supplemental ~~environmental impact statement (EIS)~~EIS in accordance with NEPA. The FERC indicated that the supplemental EIS ~~will~~would address the new and revised measures proposed by the CWA 401 certification settlement, the conditions contained in the Oregon and Idaho water quality ~~certificates,~~certifications, and the information provided in the draft biological assessments. The FERC also ~~reinstated~~reinitiated informal consultation with the USFWS and the NMFS under section 7 of the ESA. AsIn the notice of ~~the date of this report, Idaho Power believes issuance of a new HCC license by~~intent, the FERC ~~will~~predicted that the draft supplemental EIS would be published in ~~2024 or thereafter.~~June 2023 and the final supplemental EIS in December 2023; an updated NOI has not yet been issued.

As of the date of this report, Idaho Power is unable to predict the exact timing that the FERC will issue a new license order or the ultimate capital investment and ongoing operating and maintenance costs Idaho Power will incur in complying with any new license. Idaho Power estimates that the annual costs it will incur to obtain a new long-term license for the HCC, including AFUDC, are likely to range from $30 million to $40 million until issuance of the license. Subsequent to the issuance of a new license, Idaho Power expects to incur increased annual operating and maintenance costs to comply with the requirements of any new ~~license.~~license and would seek to recover those increased costs through regulatory proceedings. Although Idaho Power is unable to predict the exact timing that the FERC will issue a new license or the ultimate capital investment and ongoing operating and maintenance costs Idaho Power will incur in complying with any new license, as of the date of this report, Idaho Power believes issuance of a new HCC license by the FERC will be in 2024 or thereafter.

~~Costs~~Relicensing costs for ~~the relicensing of~~ Idaho Power's hydropower projects are recorded inas construction work in progress until new multi-year licenses are issued by the FERC, at which time the charges are transferred to electric plant in service. Idaho Power expects to seek recovery of relicensing costs and costs related to a new long-term license through the regulatory process. Relicensing costs of ~~$406~~$441 million (including AFUDC) for the HCC were included in construction work in progress at June 30, ~~2022.~~2023. As of the date of this report, the IPUC authorizes Idaho Power to include in its Idaho jurisdiction rates $8.8 million of AFUDC annually relating to the HCC relicensing project. Collecting these amounts currently will reduce future collections when HCC relicensing costs are approved for recovery in base rates. As of June 30, ~~2022,~~2023, Idaho Power's regulatory liability for collection of AFUDC relating to the HCC was approximately ~~$197~~$218 million.

American Falls Relicensing: In April 2020, the FERC formally initiated the relicensing of the American Falls hydropower facility, which is Idaho Power's largest hydropower facility outside of the HCC, with a generating capacity of 92.3 MW. Idaho Power owns the generation facility but not the structural dam itself, which is owned by the U.S. Bureau of Reclamation. The FERC recognized Idaho Power’s pre-application document, including a proposed process plan and schedule, and recognized Idaho Power’s intent to file an application for a license. AIn February 2023, following the public comment period on its draft

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license application, Idaho Power filed a final license application ~~is due to~~with the ~~FERC in 2023.~~FERC. The relicensing has begun the process of informal ESA Section 7 consultation with the USFWS and Section 106 of the National Historic Preservation Act consultation with the Idaho State Historic Preservation Office. American Falls' current license expires in 2025,

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and as of the date of this report, Idaho Power expects the FERC to issue a new license for this facility concurrent with or prior to the existing ~~license's~~license expiration.

ENVIRONMENTAL MATTERS

Overview

Idaho Power is subject to a broad range of federal, state, regional, and local laws and regulations designed to protect, restore, and enhance the environment, including the Clean Air Act (CAA), the CWA, the Resource Conservation and Recovery Act, the Toxic Substances Control Act, the Comprehensive Environmental Response, Compensation and Liability Act, and the ESA, among other laws. These laws are administered by ~~various~~a number of federal, state, and local agencies. In addition to imposing continuing compliance obligations and associated costs, these laws and regulations provide authority to regulators to levy substantial penalties for noncompliance, injunctive relief, and other sanctions. Idaho Power's two ~~jointly-owned~~co-owned coal-fired power plants and three wholly-owned natural gas-fired combustion turbine power plants are subject to many of these regulations. Idaho Power's 17 hydropower projects are also subject to ~~numerous~~a number of water discharge standards and other environmental requirements.

Compliance with current and future environmental laws and regulations may:

•increase the operating costs of generating plants;

•increase the construction costs and lead time for new facilities;

•require the modification of existing ~~generation~~generating plants, which could result in additional costs;

•require the curtailment, fuel-switching, or shut-down of existing generating plants;

•reduce the output from current generating facilities; or

•require the acquisition of alternative sources of energy or storage technology, increased transmission wheeling, or ~~require~~ construction of additional generating facilities, which could result in higher costs.

Current and future environmental laws and regulations could significantly increase the cost of operating fossil fuel-fired generation plants and constructing new generation and transmission facilities, in large part through the substantial cost of permitting activities and the required installation of additional pollution control devices. In many parts of the United States, some higher-cost, high-emission coal-fired plants have ceased operation or the plant owners have announced a near-term cessation of operation, as the cost of compliance makes the plants uneconomical to operate. The decision to cease ~~operations~~operation of the Boardman power plant in 2020 was based in part on the significant cost of compliance with environmental laws and regulations. The decision to pursue an end to participation in coal-fired operations at the Valmy plant was also based primarily on the economics of ~~operating~~continuing coal-fired generation at the plant. Beyond increasing costs generally, these environmental laws and regulations could affect IDACORP's and Idaho Power's results of operations and financial condition if the costs associated with these environmental requirements and early plant retirements ~~and new replacement resource costs~~ cannot be fully recovered in rates on a timely basis.

Part I - "Business - Utility Operations - Environmental Regulation and ~~Costs~~"Costs" in the ~~2021~~2022 Annual Report, includes a summary of Idaho Power's expected capital and operating expenditures for environmental matters during the period from ~~2022~~2023 to ~~2024.~~2025. Given the uncertainty of future environmental regulations and technological advances, there is uncertainty around near-term estimates, and Idaho Power is also unable to predict its environmental-related expenditures ~~and infrastructure investments~~ beyond ~~2024,~~2025, though they could be substantial.

A summary of notable environmental matters (including conditions and events associated with climate change) impacting, or expected to potentially impact, IDACORP and Idaho Power is included in Part II, Item 7 - "MD&A - Environmental Issues" and "MD&A - Liquidity and Capital Resources - Capital Requirements - Environmental Regulation Costs" in the ~~2021~~2022 Annual Report. ~~Developments~~Recent developments in certain environmental matters relevant to Idaho Power are described below.

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Endangered Species Act Matters

Changes to the Endangered Species Act: The listing of a species, or changes to the critical habitat designations, of fish, wildlife, or plants as threatened or endangered under the ESA, and the associated mitigation policies, may have an adverse impact on Idaho Power's ability to construct power supply, transmission, or distribution facilities or relicense or operate its hydropower facilities. In ~~August 2019~~May 2023, ~~, under the previous presidential administration,~~ the USFWS ~~and the NMFS issued~~published a set of regulatory changes to some of the standards under which listing, delisting, and reclassifications and critical habitat designations are made (2019 ESA Rules). In October 2021, in response to January 2021 Executive Orders directing federal agencies to review certain environmental regulations, the USFWS and the NMFS proposed new rules to remove certain exclusions for designating critical habitat and to rescind the prior administration's regulatory definition of habitat. ~~In July 2022, the U.S. District Court for the Northern District of California (Ninth Circuit) issued an order remanding and vacating the 2019 ESA Rules, which order applies nationwide. While the~~ ~~USFWS and the NMFS~~ ~~continue to work toward finalizing the new rules, Idaho Power plans to continue to operate under the ESA rules in effect prior to the 2019 ESA Rules.~~

~~Developments in Regulation of Sage Grouse Habitat:~~ In February 2016, a lawsuit was filed in the U.S. District Court of Idaho challenging the BLM's sage grouse resource management and land use plan revisions that became effective in 2015 under the Federal Landrevised Mitigation Policy and ~~Management Act. The lawsuit challenges the plans~~a revised ESA Compensatory Mitigation Policy (Revised Policies) which together establish fundamental mitigation principles and ~~associated EISs across the sage grouse range~~compensatory mitigation standards and alleges that the plans fail to ensure that sage grouse populations and habitats will be protected and restored in accordance with the best available science and legal mandates. Further, the complaint challenges certain exemptions provided for the Boardman-to-Hemingway and Gateway West transmission line projects. Idaho Power has intervened in the proceedings in an effort to support the exemptions provided for in the BLM's plans. If the exemptions are overturned, Idaho Power may be required to re-route the projects, which could lead to substantially higher construction and permitting costs and could delay construction.

In May 2016, a separate lawsuit was filed in the U.S. District Court of North Dakota, challenging the BLM's sage grouse resource management and land use plan revisions, including the exemptions provided for the Boardman-to-Hemingway and Gateway West transmission line projects. In October 2016, the plaintiffs amended their complaint to no longer challenge the exemptions; however, in December 2016, the North Dakota court transferred claims challenging certain Idaho land use plan amendments to the U.S. District Court for the District of Columbia. Idaho Power is participating in the proceedings in an effort to protect its interests.

In June 2017, the Secretary of the Interior issued an order directing the BLM to review the 2015 sage grouse resource management and land use plan revisions and to identify provisions that may require modification or rescission to address energy and other development of public lands. In March 2019, the BLM issued a record of decision for six EISs that modified the 2015 sage grouse plans to better align the plan with state plans, conservation measures and the Department of the Interior and BLM policy. In October 2019, the U.S. District Court for Idaho placed a preliminary injunction on theapplication guidance through implementation of the ~~BLM's March 2019 plans. In order~~ESA. The Revised Policies scale back the mitigation goal from the previous policies by including a nexus and proportionality principle to ~~address~~reinforce that government-required mitigation measures must have a clear connection with the concerns contained in the preliminary injunction, BLM initiated a supplemental EIS process that was completed in November 2020. A record of decision for the 2020 supplemental EIS was signed in January 2021. In November 2021, the BLM issued a notice of intent to address the management of sage grouse and sagebrush habitat on BLM-managed public lands in Idaho and Oregon, among other states, through a land use planning initiative. In February 2022, BLM issued a notice of intent to amend its land use plans regarding sage grouse conservation and prepare associated EISs, soliciting public comments on the planning initiative.

As of the date of this report, the above lawsuits are stayed as the parties and the courts have agreed that the processes initiated by the BLM may result in further administrative actions that could remove the need for the lawsuits.

~~Hells Canyon Relicensing Project~~: ~~In December 2004, Idaho Power and eleven other parties, including the NMFS and the USFWS, entered into an interim agreement that addresses the~~anticipated effects of the ongoing operations of the HCC on ESA listed species pending the relicensing of the project. In 2007, the FERC requested initiation of formal consultation under the ESA with the NMFS and the USFWS regarding potential effects of HCC relicensing on several listed aquatic and terrestrial species. Idaho Power prepared draft biological assessments in consultation with the USFWS and the NMFS and filed those with the FERC in October 2020. The draft biological assessments are intended to provide the necessary information to the USFWS and the NMFS to issue their biological opinion as required under the ESA. In June 2022 the FERC issued a notice of intent to prepare a draft and final supplemental EIS in accordance with NEPA. The FERC indicated that the supplemental EIS will address the new and revised measures proposed by the 401 certification settlement, the conditions contained in the Oregon and Idaho water quality certificates, and the information provided in the draft biological assessments. The FERC also reinstated informal consultation with the USFWS and NMFS under section 7 of the ESA.land use. As of the date of this report, Idaho Power ~~believes that~~is uncertain to what extent the ~~issuance of a final biological opinion during 2022 is unlikely.~~

~~Table of Contents~~Revised Policies may impact its obligations in permitting infrastructure, including relicensing its hydroelectric facilities, and transmission lines.

~~Changes to NEPA~~: In July 2020, the previous Presidential Administration's Council on Environmental Quality (CEQ) announced its final rule to narrow federal agencies' NEPA obligations (2020 NEPA Rule), which had the potential to expedite and reduce the cost of Idaho Power's permitting and right-of-way processes. NEPA applies to Idaho Power’s transmission and distribution lines that are located on federal land, as well as other company activities involving federal actions. Under Executive Order 13990 issued in January 2021, the current Presidential Administration’s CEQ was tasked with reviewing the 2020 NEPA Rule. In October 2021, the CEQ published a notice of proposed rulemaking to reverse the more narrow 2020 NEPA Rule, with minor modifications (2021 NEPA Rule). In April 2022, the CEQ published a final rule consistent with the proposed 2021 NEPA Rule, that restores the requirement that federal agencies consider all indirect and cumulative environmental impacts of infrastructure projects in their decision-making, among other things, which could delay and increase the cost of Idaho Power’s infrastructure projects. Also in April 2022, the current Presidential Administration announced that the CEQ will propose a second phase of changes to NEPA that are aimed at further climate change related reform.

Clean Air Act Matters

~~Regional Haze Rules~~Good Neighbor Plan: In accordance with federal regional haze rules under the CAA, coal-fired utility boilers are subject to regional haze - best available retrofit technology (RH BART) if they were built between 1962 and 1977 and affect any "Class I" (wilderness) areas. This includes all units at the Jim Bridger plant. In December 2009, the Wyoming Department of Environmental Quality (WDEQ) issued a RH BART permit to PacifiCorp as the operator of the Jim Bridger plant. As part of the WDEQ's long term strategy for regional haze, the permit required that PacifiCorp install selective catalytic reduction equipment for nitrogen oxide (NOx~~) control at Jim Bridger units 3 and 4 by December 31, 2015, and December 31, 2016, respectively, which has been completed, and submit an application by December 31, 2017, to install add-on NO~~x controls at Jim Bridger unit 2 by 2021 and unit 1 by 2022, which was submitted in December 2017. PacifiCorp has been negotiating with the WDEQ since 2009 to settle on terms of the timing and nature of controls for the Jim Bridger plant units. More information on the history of the permitting process for the Jim Bridger plant is included in Part II, Item 7 - "MD&A - Environmental Issues" in the 2021 Annual Report.

On December 27, 2021, Wyoming Governor Gordon issued a temporary emergency suspension of Wyoming’s existing state implementation plan (SIP) that allows Jim Bridger unit 2 to continue to operate through the end of April 2022. On January 12, 2022,June 2023, the U.S. Environmental Protection Agency (EPA) ~~issued a proposed rule that, if adopted, would disapprove~~published the 2019 proposed SIP revision, and the proposed rule was published in the Federal Register on January 18, 2022. Comments on the proposed disapproval were due by February 17, 2022, and as of the date of this report, the proposed EPA rule is pending. On February 14, 2022, the State of Wyoming filed a complaint against PacifiCorp as well as a negotiated consent decree with PacifiCorp in Wyoming state court for the threat of non-compliant operation of Jim Bridger units 1 and 2 (February Consent Decree). The consent decree requires that PacifiCorp (1) submit a revised permit application and request a SIP revision that would reflect a natural gas conversion of both units; and (2) propose an RFP for carbon capture technology at units 3 and 4. As of the date of this report, the revised permit application and RFP are pending.

On March 22, 2022, Idaho Power submitted comments to the WDEQ in support of the WDEQ's analysis that no additional requirements are necessary at the Jim Bridger plant to meet air quality standards. Idaho Power's comments included a recommendation that the WDEQ include the terms of the February Consent Decree in the SIP for the EPA's approval. In June 2022, the EPA issued an administrative compliance order on consent pursuant to which PacifiCorp agreed to comply with the contents and timeline of a SIP revision that includes emission and control requirements for units 1 and 2, and the EPA agreed to allow the Jim Bridger plant to continue generation under certain operational limits that Idaho Power believes will allow it to reliably serve its customers while the SIP revision process moves forward.

~~On April 6, 2022, the EPA issued a proposed~~final rule under the CAA called the Federal ~~Implementation Plan Addressing Regional Ozone Transport~~"Good Neighbor Plan" for the 2015 Ozone National Ambient Air Quality Standards ~~(CSAPR)~~(Good Neighbor Plan), to ~~establish NOx~~be effective August 4, 2023. The Good Neighbor Plan establishes NOx emissions budgets requiring fossil fuel-fired power plants to participate in an allowance-based ozone season trading ~~program beginning~~program. The EPA's final rule temporarily excludes power plants located in ~~2023.~~Wyoming, while the EPA reevaluates the proposed disapproval of the Wyoming state implementation plan (SIP). Refer to Part II, Item 7 - "MD&A - Environmental Issues" in the 2022 Annual Report for more information on SIPs.

In July 2023, the Ninth Circuit Court of Appeals issued a stay halting application of the Good Neighbor Plan in Nevada pending a hearing on the merits of an appeal challenging the EPA's disapproval of Nevada's SIP. As of the date of this report, Idaho Power ~~submitted comments~~continues to evaluate the specific impacts the Good Neighbor Plan could have on ~~the CSAPR on June 21, 2022, and believes that the proposed rule, if finalized, could impact~~its operations at the Valmy and Jim Bridger plants. If the Good Neighbor Plan is implemented in Nevada and ~~Valmy plants.~~Wyoming, Idaho Power ~~believes that if the proposed CSAPR were implemented,~~anticipates under certain conditions ~~the company~~it could ~~have reduced~~reduce the ability to use the full available output at the Valmy and Jim Bridger plants.

Regulation of Greenhouse Gas Emissions: In May 2023, the EPA released a proposed rule under Section 111 of the CAA to regulate greenhouse gas emissions from fossil fuel-fired power plants. The proposed rule would impose significant GHG emissions reductions on new and existing natural gas-fired generating units and coal plants expected to be operational in ~~order~~2040 and beyond. The proposed rule would require states to ~~comply with~~submit plans to the ~~CSAPR limitations.~~EPA to implement standards for existing sources within 24 months of the effective date of the emission guidelines. As of the date of this report, Idaho Power ~~will be evaluating~~continues to evaluate the specific impacts ~~to both plants~~the proposed rule could have on its operations at its three natural gas facilities, as well as the Valmy and ~~for the~~ Jim Bridger ~~plant, how~~plants. If the ~~CSAPR will interact with~~proposed rule is implemented, Idaho Power anticipates that the ~~SIP and February Consent Decree between Wyoming and PacifiCorp.~~GHG emissions reductions may under certain circumstances only be achievable by reducing unit runtimes.

Clean Water Act Matters

Definition of “Waters of the United States” Under the CWA: ~~In August~~Since 2015, the EPA and U.S. Army Corps of Engineers ~~(USACE) final rule defining~~have been attempting to define the ~~phrase~~scope of "waters of the United States" (WOTUS) under the CWA. The WOTUS definition is fundamental to the application of the CWA ~~became effective (WOTUS~~

~~Table~~because only those bodies of ~~Contents~~

~~Rule). Idaho Power believes that the 2015 rule potentially expanded federal jurisdiction~~water designated as WOTUS are protected from unlawful discharge of pollutants under the CWA beyond traditional navigable waters, interstate waters, territorial seas, tributaries, and adjacent wetlands, to a number of other waters, including waters with a "significant nexus" to those traditional waters. The WOTUS Rule was widely challenged in both federal district and circuit courts. In January 2020, the EPA and USACE finalized the first of a two-part rule to repeal the WOTUS Rule and set new and more expansive standards for determining which waters are subject to the CWA, which substantially restored the definitions and guidance used prior to the WOTUS Rule. In April 2020, the EPA and USACE published the second part of the final rule to replace the WOTUS Rule with the "Navigable Waters Protection Rule" that provides a final definition of "waters of the United States," which ultimately narrows the scope of waters subject to federal regulation under the CWA. The Navigable Waters Protection Rule became effective in June 2020. In December 2021, in response to the January 2021 Executive Orders, the EPA and USACE published a proposed rule, subject to a comment period that ended in February 2022, that restores the protections in place prior to the WOTUS Rule and establishes a new expansive definition of "waters of the United States."

In ~~January 2022,~~May 2023, the U.S. Supreme Court ~~agreed to review~~issued a ~~challenge to~~decision defining WOTUS under the ~~EPA’s assertion~~CWA and providing nationwide clarity of the federal government’s jurisdiction over ~~certain~~WOTUS. The decision restricts the federal government's ability to regulate wetlands ~~because~~that do not have a continuous surface connection with a navigable water. While not addressed in the ~~wetlands~~opinion, ephemeral streams and other water bodies that are ~~WOTUS~~not relatively permanent would also not be jurisdictional under the May 2023 decision. The current presidential administration is developing a ~~standard described~~rule to amend the previous rule published in ~~a prior~~January 2023, consistent with the U.S. Supreme ~~Court~~Court's decision. ~~While it remains unclear what~~Because the court will review, it could clarify the definition of WOTUS, or focus on the narrower question of when wetlands constitute WOTUS. The EPA has not indicated whether it plans to alter the rulemaking timeline in light of the pending U.S. Supreme Court proceedings, but EPA officials indicated that they intend to continue moving forward with the regulatory process. If the court opines on relevant statutory language before the EPA finalizes a new definition ~~of WOTUS,~~does not alter how the ~~EPA may need to consider the court’s interpretation in their regulations.~~

Idaho Power believes the repeal rule, the WOTUS Rule, the Navigable Waters Protection Rule, and the proposed new rule will continue to be challenged in court, but expects that, even if the WOTUS Rule is reinstated in Idaho or the expansive proposed new rule is enacted and should the revised definition take effect in Idaho, while it may cause Idaho Power to incur additional permitting, regulatory requirements, and other costs associated with the rule, the aggregate amount of increased costs is unlikely to have a material adverse effect on Idaho Power's operations or financial condition, in part due to the relatively arid climate of Idaho Power's service area. Similarly, because the CWA ~~as interpreted even prior to the WOTUS Rule,~~ applies to most of Idaho Power's facilities, including its hydropower plants, Idaho Power does not expect ~~reinstatement would have a material~~the new rule to materially impact on Idaho Power's operations or financial condition.

~~Section 401 Water Quality Certification:~~ CWA PermittingAs described more fully under “Relicensing of Hydropower Projects” in the "Regulatory Matters" section of this MD&A, Idaho Power filed water quality certification applications, required under Section 401 of the CWA, with the states of Idaho and Oregon requesting that each state certify that any discharges from the HCC comply with applicable state water quality standards. The states issued final certifications in May 2019, after reaching a settlement with Idaho Power on fisheries-related matters. The Oregon certification, however, was challenged in state court by three third parties. Two of the lawsuits were consolidated, and Idaho Power intervened in that lawsuit and the parties reached a settlement. The court dismissed the third challenge to the Oregon CWA 401 certification with prejudice. In December 2019, Idaho Power filed an Offer of Settlement with the FERC requesting specific language be included in the new HCC license based upon the fish settlement among Idaho, Oregon, and Idaho Power. During the first quarter of 2020, the FERC received several comments opposing the Offer of Settlement and its decision relating to the Offer of Settlement is pending as of the date of this report.

In July 2020, the EPA published a rule amending regulations intended to implement the CWA Section 401 water quality certification process (July 2020 Rule). The rule clarifies that a state must issue its water quality certification within a reasonable time period, up to one year from the certification request, and limits the scope of the certification to jurisdictional water quality matters. Further, the new regulations make clear that federal agencies, not the state departments of environmental quality, will enforce the certification conditions. The July 2020 Rule became effective in September 2020 (2020 CWA Section 401 Order). In October 2021, the Ninth Circuit Court of Appeals issued an order remanding and vacating the 2020 CWA Section 401 Order, which order applies nationwide, and requires a temporary return to the EPA's previous Section 401 of the CWA in effect since 1979. In April 2022, the U.S. Supreme Court stayed the vacatur imposed by the Ninth Circuit, and the EPA filed a notice of intent to repeal the July 2020 Rule. While the EPA finalizes a new certification rule, Idaho Power plans to continue to operate under the current CWA Section 401 regulations as described above.

Idaho Power expects the EPA to expand state and tribal authority over water quality certifications; however, such expanded authority would not likely impact the timing and cost of the HCC certification unless the FERC declines to adopt the Offer of Settlement, in which case Idaho Power would file new water quality certification applications in Idaho and Oregon with revisions necessary to address changes to the regulations, which Idaho Power cannot currently predict and could delay the timing of issuance and increase the cost of obtaining a license for the HCC.

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~~CWA Permitting:~~ : Idaho Power's hydropower generation facilities are subject to compliance and permitting obligations under the CWA. Idaho Power has been engaged for several years with the EPA, and is now engaged with the Idaho Department of Environmental Quality (IDEQ), regarding Idaho Power's CWA permitting obligations and compliance status for those facilities. Idaho Power has in the past, and expects in the future, to incur costs ~~and expenses~~ associated with those permitting and compliance ~~obligations.~~obligations, but as of the date of this report, Idaho Power is unable to estimate with any reasonable certainty those costs. Idaho

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Power also expects to incur additional ~~expenses~~costs associated with the relicensing of its ~~hydropower~~hydroelectric facilities, as discussed elsewhere in this report.

~~On April 7,~~In June 2022, Idaho Power and the IDEQ entered into a consent judgment in the district courts for the third, fourth, fifth, and sixth judicial districts of the State of Idaho to resolve a National Pollutant Discharge Elimination System permitting issue related to 15 of Idaho Power’s hydropower projects that ~~requires~~required Idaho Power to pay a $1.1 million fine, implement interim measures for compliance, and ultimately submit applications for new permits at each of the dams subject to the consent judgment. Due to a misinterpretation of law, the EPA cancelled water discharge permits in the mid-1990’s, and Idaho Power recently determined that those permits are applicable for operation of the dams. However, Idaho Power believes that the dams would have been in compliance with the earlier permits had they remained in place. As of the date of this report, Idaho Power has submitted new permit applications for nine of the dams and anticipates completing all submissions by June 2024.

OTHER MATTERS

Critical Accounting Policies and Estimates

IDACORP's and Idaho Power's discussion and analysis of their financial condition and results of operations are based upon their condensed consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles. The preparation of these financial statements requires IDACORP and Idaho Power to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues, and expenses and related disclosure of contingent assets and liabilities. On an ongoing basis, IDACORP and Idaho Power evaluate these estimates, including those estimates related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates are based on historical experience and on other assumptions and factors that are believed to be reasonable under the circumstances, and are the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. IDACORP and Idaho Power, based on their ongoing reviews, make adjustments when facts and circumstances dictate.

IDACORP’s and Idaho Power’s critical accounting policies are reviewed by the audit committees of the boards of directors. These policies have not changed materially from the discussion of those policies included under "Critical Accounting Policies and Estimates" in the ~~2021~~2022 Annual Report.

Recently Issued Accounting Pronouncements

There have been no recently issued accounting pronouncements that have had or are expected to have a material impact on IDACORP's or Idaho Power's condensed consolidated financial statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

IDACORP is exposed to market risks, including changes in interest rates, changes in commodity prices, credit risk, and equity price risk. The following discussion summarizes material changes in these risks since December 31, ~~2021,~~2022, and the financial instruments, derivative instruments, and derivative commodity instruments sensitive to changes in interest rates, commodity prices, and equity prices that were held at June 30, ~~2022.~~2023. IDACORP has not entered into any of these market-risk-sensitive instruments for trading purposes.

Interest Rate Risk

IDACORP manages interest expense and short- and long-term liquidity through a combination of fixed rate and variable rate debt. Generally, the amount of each type of debt is managed through market issuance, but interest rate swap and cap agreements with highly-rated financial institutions may be used to achieve the desired combination.

Variable Rate Debt: As of June 30, ~~2022,~~2023, IDACORP had ~~$30.1 million in~~no net ~~floating~~variable rate debt, ~~which approximated fair value. Assuming no change in financial structure, if~~as the carrying value of short-term investments exceeded the carrying value of outstanding variable ~~interest rates were to average one percentage point higher than the average~~ rate ~~on June 30, 2022, annual interest expense would increase and pre-tax earnings would decrease by approximately $0.3 million for IDACORP.~~debt.

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Fixed Rate Debt: As of June 30, ~~2022,~~2023, IDACORP had ~~$2.0~~$2.5 billion in fixed rate debt, with a fair ~~market~~ value of approximately ~~$1.9~~$2.2 billion. These instruments are fixed rate and, therefore, do not expose the companies to a loss in earnings due to changes in market interest rates. However, the fair value of these instruments would increase by approximately ~~$222~~$278 million if market interest rates were to decline by one percentage point from their June 30, ~~2022,~~2023, levels.

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Commodity Price Risk

IDACORP's exposure to changes in commodity prices is related to Idaho Power's ongoing utility operations that produce electricity to meet the demand of its retail electric customers. These changes in commodity prices are mitigated in large part by Idaho Power's Idaho and Oregon power cost adjustment mechanisms. To supplement its ~~generation~~supply resources and balance its supply of power with the demand of its retail customers, Idaho Power participates in the wholesale marketplace. IDACORP's commodity price risk as of June 30, ~~2022,~~2023, had not changed materially from that reported in Item 7A of IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2021 (2021~~2022 (2022 Annual Report). Information regarding Idaho Power’s use of derivative instruments to manage commodity price risk can be found in Note 1211 - "Derivative Financial Instruments" to the condensed consolidated financial statements included in this report.

Credit Risk

IDACORP is subject to credit risk based on Idaho Power's activity with market counterparties. Idaho Power is exposed to this risk to the extent that a counterparty may fail to fulfill a contractual obligation to provide energy, purchase energy, or complete financial settlement for market activities. Idaho Power mitigates this exposure by actively establishing credit limits; measuring, monitoring, and reporting credit risk; using appropriate contractual arrangements; and transferring credit risk through the use of financial guarantees, cash, or letters of credit. Idaho Power maintains a current list of acceptable counterparties and credit limits.

The use of performance assurance collateral in the form of cash, letters of credit, or guarantees is common industry practice. Idaho Power maintains margin agreements relating to its wholesale commodity contracts that allow performance assurance collateral to be requested of and/or posted with certain counterparties. As of June 30, ~~2022,~~2023, Idaho Power posted ~~$1.2~~$44 million performance assurance collateral related to these contracts. Should Idaho Power experience a reduction in its credit rating on Idaho Power's unsecured debt to below investment grade, Idaho Power could be subject to requests by its wholesale counterparties to post additional performance assurance collateral. Counterparties to derivative instruments and other forward contracts could request immediate payment or demand immediate ongoing full daily collateralization on derivative instruments and contracts in net liability positions. Based upon Idaho Power's energy and fuel portfolio and market conditions as of June 30, ~~2022,~~2023, the amount of collateral that could be requested upon a downgrade to below investment grade was approximately ~~$14.5~~$18.7 million. To minimize capital requirements, Idaho Power actively monitors the portfolio exposure and the potential exposure to additional requests for performance assurance collateral calls through sensitivity analysis.

IDACORP's credit risk related to uncollectible accounts, net of amounts reserved, as of June 30, ~~2022,~~2023, had not changed materially from that reported in Item 7A of the ~~2021~~2022 Annual Report, except as disclosed in Note 4 - "Revenues" to the condensed consolidated financial statements included in this report. Additional information regarding Idaho Power’s management of credit risk and credit contingent features can be found in Note 1211 - "Derivative Financial Instruments" to the condensed consolidated financial statements included in this report.

Equity Price Risk

IDACORP is exposed to price fluctuations in equity markets, primarily through Idaho Power's defined benefit pension plan assets, a mine reclamation trust fund owned by an equity-method investment of Idaho Power, and other equity security investments at Idaho Power. The equity securities held by the pension plan and in such accounts are diversified to achieve broad market participation and reduce the impact of any single investment, sector, or geographic region. Idaho Power has established asset allocation targets for the pension plan holdings, which are described in Note 1011 - "Benefit Plans" to the consolidated financial statements included in the ~~2021~~2022 Annual Report.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

IDACORP: The Chief Executive Officer and the Chief Financial Officer of IDACORP, based on their evaluation of IDACORP’s disclosure controls and procedures (pursuant to Rule 13a-15(b) of the Securities Exchange Act of 1934 (Exchange Act)) as of June 30, ~~2022,~~2023, have concluded that IDACORP’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) are effective as of that date.

Idaho Power: The Chief Executive Officer and the Chief Financial Officer of Idaho Power, based on their evaluation of Idaho Power’s disclosure controls and procedures (pursuant to Rule 13a-15(b) of the Exchange Act) as of June 30, ~~2022,~~2023, have

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concluded that Idaho Power’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) are effective as of that date.

Changes in Internal Control over Financial Reporting

There have been no changes in IDACORP's or Idaho Power's internal control over financial reporting during the quarter ended June 30, ~~2022,~~2023, that have materially affected, or are reasonably likely to materially affect, IDACORP's or Idaho Power's internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

On April 7, 2022, Idaho Power and the Idaho Department of Environmental Quality entered into a consent judgment in the District Courts for the Third, Fourth, Fifth, and Sixth Judicial Districts of the State of Idaho to resolve a National Pollutant Discharge Elimination System permitting issue related to 15 of Idaho Power’s hydropower projects. The consent judgement requires Idaho Power to pay a $1.1 million fine, implement interim measures for compliance, and ultimately submit applications for new permits at each of the dams subject to the consent judgment. Due to a misinterpretation, the U.S. Environmental Protection Agency cancelled water discharge permits in the mid-1990’s, and Idaho Power recently determined that those permits are applicable for operation of the dams and self-reported the permitting issue. However, Idaho Power believes that the dams would have been in compliance with the earlier permits had they remained in place.None

ITEM 1A. RISK FACTORS

The factors discussed in Part I - Item 1A - "Risk Factors" in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2021,~~2022, could materially affect IDACORP’s and Idaho Power's business, financial condition, or future results. In addition to those risk factors and other risks discussed in this report, see "Cautionary Note Regarding Forward-Looking Statements" in this report for additional factors that could have a significant impact on IDACORP's or Idaho Power's operations, results of operations, or financial condition and could cause actual results to differ materially from those anticipated in forward-looking statements.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Restrictions on Dividends

See Note 6 - "Common Stock" to the condensed consolidated financial statements included in this report for a description of restrictions on IDACORP's and Idaho Power's payment of dividends.

Issuer Purchases of Equity Securities

IDACORP did not repurchase any shares of its common stock during the quarter ended June 30, ~~2022.~~2023.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. MINE SAFETY DISCLOSURES

Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95.1 of this report, which is incorporated herein by reference.

ITEM 5. OTHER INFORMATION

~~None~~During the three months ended June 30, 2023, none of IDACORP's or Idaho Power's directors or officers (as defined in Rule 16a-1(f) of the Securities Exchange Act of 1934) adopted, terminated, or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (as such terms are defined in Item 408 of Regulation S-K of the Securities Act of 1933).

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ITEM 6. EXHIBITS

The following exhibits are filed or furnished, as applicable, with the Quarterly Report on Form 10-Q for the quarter ended June 30, ~~2022:~~2023:
Incorporated by Reference
Exhibit No. Exhibit Description Form File No. Exhibit No. Date Included Herewith
4.1
Idaho Power Company Fiftieth Supplemental Indenture, d ated effective as of June 30, 2022, to Mortgage and Deed of Trust, dated as of October 1, 1937
8-K 1-3198 4.1 6/30/2022
15.1
Letter Re: Unaudited Interim Financial Information
X
15.2
Letter Re: Unaudited Interim Financial Information
X
31.1
Certification of IDACORP, Inc. Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
31.2
Certification of IDACORP, Inc. Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
31.3
Certification of Idaho Power Company Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
31.4
Certification of Idaho Power Company Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
32.1
Certification of IDACORP, Inc. Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
32.2
Certification of IDACORP, Inc. Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
32.3
Certification of Idaho Power Company Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
32.4
Certification of Idaho Power Company Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
95.1
Mine Safety Disclosures
X
101.SCH Inline XBRL Taxonomy Extension Schema Document X
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document X
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document X
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document X
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase Document X
104 Cover Page Interactive Data File (formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.) X

Incorporated by Reference

Exhibit No.

Exhibit Description

Form

File No.

Exhibit No.

Date

Included Herewith

15.1

Letter Re: Unaudited Interim Financial Information

15.2

Letter Re: Unaudited Interim Financial Information

31.1

Certification of IDACORP, Inc. Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2

Certification of IDACORP, Inc. Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.3

Certification of Idaho Power Company Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.4

Certification of Idaho Power Company Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1

Certification of IDACORP, Inc. Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2

Certification of IDACORP, Inc. Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.3

Certification of Idaho Power Company Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.4

Certification of Idaho Power Company Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

95.1

Mine Safety Disclosures

101.SCH

Inline XBRL Taxonomy Extension Schema Document

101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB

Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE

Inline XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

104

Cover Page Interactive Data File (formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.)

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.


		IDACORP, INC.
		(Registrant)



Date:	August ~~4, 2022~~3, 2023	By:	/s/ Lisa A. Grow
			Lisa A. Grow
			President and Chief Executive Officer

Date:	August ~~4, 2022~~3, 2023	By:	/s/ Brian R. Buckham
			Brian R. Buckham
			Senior Vice President and Chief Financial Officer






		IDAHO POWER COMPANY
		(Registrant)



Date:	August ~~4, 2022~~3, 2023	By:	/s/ Lisa A. Grow
			Lisa A. Grow
			President and Chief Executive Officer

Date:	August ~~4, 2022~~3, 2023	By:	/s/ Brian R. Buckham
			Brian R. Buckham
			Senior Vice President and Chief Financial Officer

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	2022	2023	2024-2026
Expected capital expenditures (excluding AFUDC)	$500-$520	$690-$715	$1,450-$1,550