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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~~September 30, 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 ☒ No ☐ Idaho Power Company: Yes ☒ 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 ☒ No ☐ Idaho Power Company: Yes ☒ 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 ☒ 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 ☒ 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 ☒ Idaho Power Company: Yes ☐ No ☒

Number of shares of common stock outstanding as of ~~July 28,~~October 27, 2023:

IDACORP, Inc.: ~~50,614,789~~50,615,237

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		3435
	Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			3637
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			6164
	Item 4. Controls and Procedures			6265

Part II. Other Information

	Item 1. Legal Proceedings			6466
	Item 1A. Risk Factors			6466
	Item 2. Unregistered Sales of Equity Securities, ~~and~~ Use of Proceeds, and Issuer Purchases of Equity Securities			6466
	Item 3. Defaults Upon Senior Securities			6466
	Item 4. Mine Safety Disclosures			6466
	Item 5. Other Information			6466
	Item 6. Exhibits			6567

Signatures				6668

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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:

2022 Annual Report	-	IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 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
BPA	-	Bonneville Power Administration
CPCN	-	Certificate of Public Convenience and Necessity
CWA	-	Clean Water Act
EFSC	-	Energy Facility Siting Council
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.
IDEQ	-	Idaho Department of Environmental Quality
IERCo	-	Idaho Energy Resources Co., a subsidiary of Idaho Power Company
IFS	-	IDACORP Financial Services, Inc., a subsidiary of IDACORP, Inc.
IPUC	-	Idaho Public Utilities Commission
IRP	-	Integrated Resource Plan
Jim Bridger plant	-	Jim Bridger 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
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 I and Security Plan for Senior Management Employees II, together
USFWS	-	U.S. Fish and Wildlife Service
Valmy plant	-	Idaho Power's jointly-owned coal-fired generating plant in Valmy, Nevada
WMP	-	Wildfire Mitigation Plan
WOTUS	-	Waters of the United States
~~WRAP~~	-	~~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," "intends," "potential," "plans," "predicts," "preliminary," "projects," "targets," "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~~and 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~~the 2022 Annual Report, ~~on Form 10-K for the year ended December 31, 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),~~SEC, and the following important factors:

•decisions by the Idaho and Oregon public utilities commissions and the ~~Federal Energy Regulatory Commission~~FERC 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~~expenses 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 and failures 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;

•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 related impact on recruiting employees, and the ability to adjust to fluctuations in labor costs;

•changes in, failure to comply with, and costs of 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 associated with increased costs through 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, 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 vulnerabilities to the power grid;

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•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;

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•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 lack of counterparty and 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,~~output; damage company assets, operations, or reputation; subject Idaho Power to third-party claims for property damage, personal injury, or loss of life; or result in the imposition of fines and penalties; ~~insurance coverage for 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’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;

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

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

•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;

•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;

•ability to obtain debt and equity financing or refinance existing debt when necessary and on 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, 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;

•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, contractual covenants and restrictions, and regulatory limitations, and in light of credit rating ~~considerations, contractual covenants and restrictions, and regulatory limitations;~~considerations; 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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			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	$	412,727	$	357,668	$	842,065	$	701,589	Electric utility revenues	$	509,635	$	517,101	$	1,351,700	$	1,218,690
Other	Other	1,111		1,055		1,432		1,422		Other	1,271		911		2,703		2,333
Total operating revenues	Total operating revenues	413,838		358,723		843,497		703,011		Total operating revenues	510,906		518,012		1,354,403		1,221,023

Operating Expenses:	Operating Expenses:									Operating Expenses:
Electric utility:	Electric utility:									Electric utility:
Purchased power	Purchased power	91,460		91,727		262,554		177,151		Purchased power	142,851		192,884		405,404		370,035
Fuel expense	Fuel expense	31,113		34,417		120,194		80,119		Fuel expense	71,723		63,631		191,917		143,750
Power cost adjustment	Power cost adjustment	49,629		(426)		(1,708)		(825)		Power cost adjustment	5,899		(30,806)		4,191		(31,631)
Other operations and maintenance	Other operations and maintenance	97,123		100,556		189,164		192,642		Other operations and maintenance	95,824		100,679		284,988		293,322
Energy efficiency programs	Energy efficiency programs	6,552		6,609		11,767		13,198		Energy efficiency programs	10,498		8,292		22,265		21,490
Depreciation	Depreciation	47,108		34,830		92,499		79,287		Depreciation	50,832		45,951		143,331		125,238
Other electric utility operating expenses	Other electric utility operating expenses	7,846		8,865		16,871		17,765		Other electric utility operating expenses	6,297		8,780		23,169		26,544
Total electric utility operating expenses	Total electric utility operating expenses	330,831		276,578		691,341		559,337		Total electric utility operating expenses	383,924		389,411		1,075,265		948,748
Other	Other	713		639		1,758		1,500		Other	694		377		2,453		1,877
Total operating expenses	Total operating expenses	331,544		277,217		693,099		560,837		Total operating expenses	384,618		389,788		1,077,718		950,625

Operating Income	Operating Income	82,294		81,506		150,398		142,174		Operating Income	126,288		128,224		276,685		270,398

Nonoperating (Income) Expense:	Nonoperating (Income) Expense:									Nonoperating (Income) Expense:
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(11,173)		(9,287)		(21,081)		(18,410)		Allowance for equity funds used during construction	(11,044)		(9,461)		(32,125)		(27,872)
Earnings of unconsolidated equity-method investments	Earnings of unconsolidated equity-method investments	(2,739)		(2,288)		(5,192)		(4,596)		Earnings of unconsolidated equity-method investments	(4,195)		(4,098)		(9,387)		(8,694)
Interest on long-term debt	Interest on long-term debt	28,579		21,374		53,547		42,443		Interest on long-term debt	29,361		22,093		82,908		64,536
Other interest	Other interest	4,609		3,860		9,363		7,675		Other interest	5,572		4,188		14,935		11,864
Allowance for borrowed funds used during construction	Allowance for borrowed funds used during construction	(5,161)		(3,481)		(9,389)		(6,865)		Allowance for borrowed funds used during construction	(4,903)		(3,534)		(14,291)		(10,399)
Other income, net	Other income, net	(8,816)		(1,551)		(16,964)		(3,163)		Other income, net	(7,924)		(3,042)		(24,890)		(6,206)
Total nonoperating expense, net	Total nonoperating expense, net	5,299		8,627		10,284		17,084		Total nonoperating expense, net	6,867		6,146		17,150		23,229

Income Before Income Taxes	Income Before Income Taxes	76,995		72,879		140,114		125,090		Income Before Income Taxes	119,421		122,078		259,535		247,169

Income Tax Expense	Income Tax Expense	8,131		8,291		15,226		14,317		Income Tax Expense	13,774		15,450		29,000		29,768

Net Income	Net Income	68,864		64,588		124,888		110,773		Net Income	105,647		106,628		230,535		217,401
Income attributable to noncontrolling interests	Income attributable to noncontrolling interests	(290)		(301)		(216)		(225)		Income attributable to noncontrolling interests	(383)		(248)		(599)		(473)
Net Income Attributable to IDACORP, Inc.	Net Income Attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548	Net Income Attributable to IDACORP, Inc.	$	105,264	$	106,380	$	229,936	$	216,928

Weighted Average Common Shares Outstanding - Basic	Weighted Average Common Shares Outstanding - Basic	50,725		50,668		50,707		50,650		Weighted Average Common Shares Outstanding - Basic	50,726		50,668		50,713		50,656
Weighted Average Common Shares Outstanding - Diluted	Weighted Average Common Shares Outstanding - Diluted	50,758		50,687		50,741		50,673		Weighted Average Common Shares Outstanding - Diluted	50,805		50,722		50,762		50,689
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	$	1.35	$	1.27	$	2.46	$	2.18	Earnings Attributable to IDACORP, Inc. - Basic	$	2.08	$	2.10	$	4.53	$	4.28
Earnings Attributable to IDACORP, Inc. - Diluted	Earnings Attributable to IDACORP, Inc. - Diluted	$	1.35	$	1.27	$	2.46	$	2.18	Earnings Attributable to IDACORP, Inc. - Diluted	$	2.07	$	2.10	$	4.53	$	4.28

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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Net Income	Net Income	$	68,864	$	64,588	$	124,888	$	110,773	Net Income	$	105,647	$	106,628	$	230,535	$	217,401
Other Comprehensive Income:	Other Comprehensive Income:									Other Comprehensive Income:

Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively		147		837		293		1,674
Unfunded pension liability adjustment, net of tax of $51, $290, $153, and $870, respectively										Unfunded pension liability adjustment, net of tax of $51, $290, $153, and $870, respectively	146		837		439		2,511
Total Comprehensive Income	Total Comprehensive Income	69,011		65,425		125,181		112,447		Total Comprehensive Income	105,793		107,465		230,974		219,912
Income attributable to noncontrolling interests	Income attributable to noncontrolling interests	(290)		(301)		(216)		(225)		Income attributable to noncontrolling interests	(383)		(248)		(599)		(473)
Comprehensive Income Attributable to IDACORP, Inc.	Comprehensive Income Attributable to IDACORP, Inc.	$	68,721	$	65,124	$	124,965	$	112,222	Comprehensive Income Attributable to IDACORP, Inc.	$	105,410	$	107,217	$	230,375	$	219,439

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2023		December 31, 2022			September 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	$	134,779	$	177,577	Cash and cash equivalents	$	445,489	$	177,577

Receivables:	Receivables:					Receivables:
Customer (net of allowance of $3,856 and $5,034, respectively)		112,730		114,173
Other (net of allowance of $567 and $512, respectively)		56,419		51,179
Customer (net of allowance of $4,135 and $5,034, respectively)						Customer (net of allowance of $4,135 and $5,034, respectively)	135,021		114,173
Other (net of allowance of $587 and $512, respectively)						Other (net of allowance of $587 and $512, respectively)	36,151		51,179
Income taxes receivable	Income taxes receivable	—		13,734		Income taxes receivable	—		13,734
Accrued unbilled revenues	Accrued unbilled revenues	93,000		84,862		Accrued unbilled revenues	81,533		84,862
Materials and supplies (at average cost)	Materials and supplies (at average cost)	121,215		92,461		Materials and supplies (at average cost)	131,616		92,461
Fuel stock (at average cost)	Fuel stock (at average cost)	16,498		14,762		Fuel stock (at average cost)	20,950		14,762
Prepayments	Prepayments	23,832		24,517		Prepayments	23,078		24,517
Current regulatory assets	Current regulatory assets	174,848		80,049		Current regulatory assets	163,818		80,049
Other	Other	313		40,339		Other	496		40,339
Total current assets	Total current assets	733,634		693,653		Total current assets	1,038,152		693,653
Investments	Investments	126,839		121,352		Investments	157,513		121,352
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Utility plant in service	Utility plant in service	6,984,783		6,828,467		Utility plant in service	7,148,293		6,828,467
Accumulated provision for depreciation	Accumulated provision for depreciation	(2,544,166)		(2,465,279)		Accumulated provision for depreciation	(2,575,485)		(2,465,279)
Utility plant in service - net	Utility plant in service - net	4,440,617		4,363,188		Utility plant in service - net	4,572,808		4,363,188
Construction work in progress	Construction work in progress	990,181		785,706		Construction work in progress	955,276		785,706
Utility plant held for future use	Utility plant held for future use	8,860		7,130		Utility plant held for future use	9,491		7,130
Other property, net of accumulated depreciation	Other property, net of accumulated depreciation	16,466		16,946		Other property, net of accumulated depreciation	16,357		16,946
Property, plant and equipment - net	Property, plant and equipment - net	5,456,124		5,172,970		Property, plant and equipment - net	5,553,932		5,172,970
Other Assets:	Other Assets:					Other Assets:
Company-owned life insurance	Company-owned life insurance	77,999		73,944		Company-owned life insurance	79,861		73,944
Regulatory assets	Regulatory assets	1,381,398		1,421,912		Regulatory assets	1,398,652		1,421,912

Other	Other	63,074		59,427		Other	65,424		59,427
Total other assets	Total other assets	1,522,471		1,555,283		Total other assets	1,543,937		1,555,283
Total	Total	$	7,839,068	$	7,543,258	Total	$	8,293,534	$	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, 2023		December 31, 2022			September 30, 2023		December 31, 2022
		(in thousands)					(in thousands)
Liabilities and Equity	Liabilities and Equity					Liabilities and Equity

Current Liabilities:	Current Liabilities:					Current Liabilities:

Accounts payable	Accounts payable	$	223,653	$	292,719	Accounts payable	$	227,348	$	292,719
Taxes accrued	Taxes accrued	30,640		8,565		Taxes accrued	36,005		8,565
Interest accrued	Interest accrued	32,026		24,060		Interest accrued	21,733		24,060
Accrued compensation	Accrued compensation	47,948		59,265		Accrued compensation	54,028		59,265
Current regulatory liabilities	Current regulatory liabilities	6,405		63,957		Current regulatory liabilities	8,620		63,957
Advances from customers	Advances from customers	91,262		72,222		Advances from customers	103,860		72,222
Other	Other	36,404		27,777		Other	37,336		27,777
Total current liabilities	Total current liabilities	468,338		548,565		Total current liabilities	488,930		548,565
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes	Deferred income taxes	861,478		873,916		Deferred income taxes	878,945		873,916
Regulatory liabilities	Regulatory liabilities	803,547		796,644		Regulatory liabilities	815,075		796,644
Pension and other postretirement benefits	Pension and other postretirement benefits	238,777		238,037		Pension and other postretirement benefits	204,604		238,037
Other	Other	123,221		77,336		Other	150,966		77,336
Total other liabilities	Total other liabilities	2,027,023		1,985,933		Total other liabilities	2,049,590		1,985,933
Long-Term Debt	Long-Term Debt	2,482,352		2,194,145		Long-Term Debt	2,826,150		2,194,145
Commitments and Contingencies	Commitments and Contingencies					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; 50,615 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		Common stock, no par value (120,000 shares authorized; 50,615 and 50,562 shares issued, respectively)	886,243		882,189
Retained earnings	Retained earnings	1,982,083		1,937,972		Retained earnings	2,047,129		1,937,972
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(12,629)		(12,922)		Accumulated other comprehensive loss	(12,483)		(12,922)

Total IDACORP, Inc. shareholders’ equity	Total IDACORP, Inc. shareholders’ equity	2,853,763		2,807,239		Total IDACORP, Inc. shareholders’ equity	2,920,889		2,807,239
Noncontrolling interests	Noncontrolling interests	7,592		7,376		Noncontrolling interests	7,975		7,376
Total equity	Total equity	2,861,355		2,814,615		Total equity	2,928,864		2,814,615
Total	Total	$	7,839,068	$	7,543,258	Total	$	8,293,534	$	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,					Nine months ended September 30,
		2023		2022			2023		2022
		(in thousands)					(in thousands)
Operating Activities:	Operating Activities:					Operating Activities:
Net income	Net income	$	124,888	$	110,773	Net income	$	230,535	$	217,401
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	94,677		81,351		Depreciation and amortization	146,645		127,335
Deferred income taxes and investment tax credits	Deferred income taxes and investment tax credits	(15,209)		(16,953)		Deferred income taxes and investment tax credits	300		(16,850)
Changes in regulatory assets and liabilities	Changes in regulatory assets and liabilities	(8,255)		8,658		Changes in regulatory assets and liabilities	1,585		(1,361)
Pension and postretirement benefit plan expense	Pension and postretirement benefit plan expense	13,626		14,484		Pension and postretirement benefit plan expense	20,390		21,744
Contributions to pension and postretirement benefit plans	Contributions to pension and postretirement benefit plans	(13,818)		(12,122)		Contributions to pension and postretirement benefit plans	(54,388)		(43,143)
Earnings of equity-method investments	Earnings of equity-method investments	(5,192)		(4,596)		Earnings of equity-method investments	(9,387)		(8,694)
Distributions from equity-method investments	Distributions from equity-method investments	—		4,265		Distributions from equity-method investments	1,250		7,963
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(21,081)		(18,410)		Allowance for equity funds used during construction	(32,125)		(27,872)
Other non-cash adjustments to net income, net	Other non-cash adjustments to net income, net	3,550		5,953		Other non-cash adjustments to net income, net	6,115		9,064
Change in:	Change in:					Change in:
Accounts receivable and unbilled revenues	Accounts receivable and unbilled revenues	(28,539)		(31,690)		Accounts receivable and unbilled revenues	(10,691)		(58,113)
Prepayments	Prepayments	(2,762)		743		Prepayments	(2,669)		3,356
Materials, supplies, and fuel stock	Materials, supplies, and fuel stock	(30,490)		858		Materials, supplies, and fuel stock	(45,343)		3,662
Accounts and wages payable	Accounts and wages payable	(138,469)		(23,439)		Accounts and wages payable	(116,417)		19,507
Taxes accrued/receivable	Taxes accrued/receivable	35,809		31,253		Taxes accrued/receivable	41,174		26,128
Other assets and liabilities	Other assets and liabilities	(1,956)		4,827		Other assets and liabilities	(14,943)		(11,152)
Net cash provided by operating activities	Net cash provided by operating activities	6,779		155,955		Net cash provided by operating activities	162,031		268,975
Investing Activities:	Investing Activities:					Investing Activities:
Additions to property, plant and equipment	Additions to property, plant and equipment	(274,167)		(194,094)		Additions to property, plant and equipment	(427,211)		(305,271)
Payments received from transmission project joint funding partners	Payments received from transmission project joint funding partners	8,953		5,531		Payments received from transmission project joint funding partners	14,920		10,979

Investments in affordable housing and other real estate tax credits projects	Investments in affordable housing and other real estate tax credits projects	135		(2,665)		Investments in affordable housing and other real estate tax credits projects	(2,742)		(10,183)

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	—		11,287
Purchases of equity securities	Purchases of equity securities	(1,926)		(27,942)		Purchases of equity securities	(3,283)		(28,888)
Purchases of held-to-maturity securities	Purchases of held-to-maturity securities	(733)		(29,692)		Purchases of held-to-maturity securities	(868)		(31,017)
Proceeds from the sale of equity securities	Proceeds from the sale of equity securities	4,401		52,833		Proceeds from the sale of equity securities	6,252		56,728
Purchases of short-term investments	Purchases of short-term investments	—		(25,000)		Purchases of short-term investments	—		(25,000)

Maturities of short-term investments						Maturities of short-term investments	—		25,000

Other	Other	4,438		6,767		Other	1,051		5,982
Net cash used in investing activities	Net cash used in investing activities	(263,799)		(203,927)		Net cash used in investing activities	(411,881)		(290,383)
Financing Activities:	Financing Activities:					Financing Activities:
Issuance of long-term debt	Issuance of long-term debt	522,000		150,000		Issuance of long-term debt	872,000		150,000
Discount on issuance of long-term debt	Discount on issuance of long-term debt	(3,772)		—		Discount on issuance of long-term debt	(7,006)		—
Retirement of long-term debt	Retirement of long-term debt	(225,000)		—		Retirement of long-term debt	(225,000)		—
Dividends on common stock	Dividends on common stock	(80,538)		(76,339)		Dividends on common stock	(120,578)		(114,308)

Tax withholdings on net settlements of share-based awards	Tax withholdings on net settlements of share-based awards	(3,255)		(2,958)		Tax withholdings on net settlements of share-based awards	(3,274)		(3,111)

Other	Other	4,787		(88)		Other	1,620		(187)
Net cash provided by financing activities	Net cash provided by financing activities	214,222		70,615		Net cash provided by financing activities	517,762		32,394
Net (decrease) increase in cash and cash equivalents		(42,798)		22,643
Net increase in cash and cash equivalents						Net increase in cash and cash equivalents	267,912		10,986
Cash and cash equivalents at beginning of the period	Cash and cash equivalents at beginning of the period	177,577		215,243		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	$	134,779	$	237,886	Cash and cash equivalents at end of the period	$	445,489	$	226,229
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	Income taxes	$	1,900	$	38,220
Interest (net of amount capitalized)	Interest (net of amount capitalized)	$	43,927	$	41,657	Interest (net of amount capitalized)	$	82,614	$	68,057
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	$	137,717	$	70,063	Additions to property, plant and equipment in accounts payable	$	127,076	$	65,374

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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			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	$	882,104	$	875,067	$	882,189	$	874,896	Balance at beginning of period	$	884,309	$	877,362	$	882,189	$	874,896
Share-based compensation expense	Share-based compensation expense	2,167		2,262		5,304		5,364		Share-based compensation expense	1,920		2,519		7,224		7,883
Tax withholdings on net settlements of share-based awards	Tax withholdings on net settlements of share-based awards	—		—		(3,255)		(2,958)		Tax withholdings on net settlements of share-based awards	(19)		(153)		(3,274)		(3,111)

Other	Other	38		33		71		60		Other	33		32		104		92
Balance at end of period	Balance at end of period	884,309		877,362		884,309		877,362		Balance at end of period	886,243		879,760		886,243		879,760
Retained Earnings	Retained Earnings									Retained Earnings
Balance at beginning of period	Balance at beginning of period	1,953,727		1,841,644		1,937,972		1,833,580		Balance at beginning of period	1,982,083		1,867,811		1,937,972		1,833,580
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	68,574		64,287		124,672		110,548		Net income attributable to IDACORP, Inc.	105,264		106,380		229,936		216,928
Common stock dividends ($0.79, $0.75, $1.58, and $1.50 per share, respectively)		(40,218)		(38,120)		(80,561)		(76,317)
Common stock dividends ($0.79, $0.75, $2.37, and $2.25 per share, respectively)										Common stock dividends ($0.79, $0.75, $2.37, and $2.25 per share, respectively)	(40,218)		(38,124)		(120,779)		(114,441)
Balance at end of period	Balance at end of period	1,982,083		1,867,811		1,982,083		1,867,811		Balance at end of period	2,047,129		1,936,067		2,047,129		1,936,067
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss									Accumulated Other Comprehensive Loss
Balance at beginning of period	Balance at beginning of period	(12,776)		(39,203)		(12,922)		(40,040)		Balance at beginning of period	(12,629)		(38,366)		(12,922)		(40,040)
Unfunded pension liability adjustment (net of tax)	Unfunded pension liability adjustment (net of tax)	147		837		293		1,674		Unfunded pension liability adjustment (net of tax)	146		837		439		2,511
Balance at end of period	Balance at end of period	(12,629)		(38,366)		(12,629)		(38,366)		Balance at end of period	(12,483)		(37,529)		(12,483)		(37,529)

Total IDACORP, Inc. shareholders’ equity at end of period	Total IDACORP, Inc. shareholders’ equity at end of period	2,853,763		2,706,807		2,853,763		2,706,807		Total IDACORP, Inc. shareholders’ equity at end of period	2,920,889		2,778,298		2,920,889		2,778,298
Noncontrolling Interests	Noncontrolling Interests									Noncontrolling Interests
Balance at beginning of period	Balance at beginning of period	7,302		6,722		7,376		6,798		Balance at beginning of period	7,592		7,023		7,376		6,798
Net income attributable to noncontrolling interests	Net income attributable to noncontrolling interests	290		301		216		225		Net income attributable to noncontrolling interests	383		248		599		473
Balance at end of period	Balance at end of period	7,592		7,023		7,592		7,023		Balance at end of period	7,975		7,271		7,975		7,271
Total equity at end of period	Total equity at end of period	$	2,861,355	$	2,713,830	$	2,861,355	$	2,713,830	Total equity at end of period	$	2,928,864	$	2,785,569	$	2,928,864	$	2,785,569

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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Operating Revenues	Operating Revenues	$	412,727	$	357,668	$	842,065	$	701,589	Operating Revenues	$	509,635	$	517,101	$	1,351,700	$	1,218,690

Operating Expenses:	Operating Expenses:									Operating Expenses:
Operation:	Operation:									Operation:
Purchased power	Purchased power	91,460		91,727		262,554		177,151		Purchased power	142,851		192,884		405,404		370,035
Fuel expense	Fuel expense	31,113		34,417		120,194		80,119		Fuel expense	71,723		63,631		191,917		143,750
Power cost adjustment	Power cost adjustment	49,629		(426)		(1,708)		(825)		Power cost adjustment	5,899		(30,806)		4,191		(31,631)
Other operations and maintenance	Other operations and maintenance	97,123		100,556		189,164		192,642		Other operations and maintenance	95,824		100,679		284,988		293,322
Energy efficiency programs	Energy efficiency programs	6,552		6,609		11,767		13,198		Energy efficiency programs	10,498		8,292		22,265		21,490
Depreciation	Depreciation	47,108		34,830		92,499		79,287		Depreciation	50,832		45,951		143,331		125,238
Other operating expenses	Other operating expenses	7,846		8,865		16,871		17,765		Other operating expenses	6,297		8,780		23,169		26,544
Total operating expenses	Total operating expenses	330,831		276,578		691,341		559,337		Total operating expenses	383,924		389,411		1,075,265		948,748

Operating Income	Operating Income	81,896		81,090		150,724		142,252		Operating Income	125,711		127,690		276,435		269,942

Nonoperating (Income) Expense:	Nonoperating (Income) Expense:									Nonoperating (Income) Expense:
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(11,173)		(9,287)		(21,081)		(18,410)		Allowance for equity funds used during construction	(11,044)		(9,461)		(32,125)		(27,872)
Earnings of unconsolidated equity-method investments	Earnings of unconsolidated equity-method investments	(1,923)		(1,784)		(4,395)		(4,265)		Earnings of unconsolidated equity-method investments	(3,007)		(3,048)		(7,402)		(7,313)
Interest on long-term debt	Interest on long-term debt	28,579		21,374		53,547		42,443		Interest on long-term debt	29,361		22,093		82,908		64,536
Other interest	Other interest	4,529		3,854		9,203		7,665		Other interest	5,491		3,948		14,693		11,613
Allowance for borrowed funds used during construction	Allowance for borrowed funds used during construction	(5,161)		(3,481)		(9,389)		(6,865)		Allowance for borrowed funds used during construction	(4,903)		(3,534)		(14,291)		(10,399)
Other income, net	Other income, net	(8,319)		(1,337)		(15,845)		(2,978)		Other income, net	(7,588)		(2,245)		(23,434)		(5,222)
Total nonoperating expense, net	Total nonoperating expense, net	6,532		9,339		12,040		17,590		Total nonoperating expense, net	8,310		7,753		20,349		25,343

Income Before Income Taxes	Income Before Income Taxes	75,364		71,751		138,684		124,662		Income Before Income Taxes	117,401		119,937		256,086		244,599

Income Tax Expense	Income Tax Expense	8,284		9,316		15,894		16,013		Income Tax Expense	14,379		15,405		30,274		31,418

Net Income	Net Income	$	67,080	$	62,435	$	122,790	$	108,649	Net Income	$	103,022	$	104,532	$	225,812	$	213,181

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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
		(in thousands)				(in thousands)					(in thousands)				(in thousands)

Net Income	Net Income	$	67,080	$	62,435	$	122,790	$	108,649	Net Income	$	103,022	$	104,532	$	225,812	$	213,181
Other Comprehensive Income:	Other Comprehensive Income:									Other Comprehensive Income:

Unfunded pension liability adjustment, net of tax of $51, $290, $102, and $580, respectively		147		837		293		1,674
Unfunded pension liability adjustment, net of tax of $51, $290, $153, and $870, respectively										Unfunded pension liability adjustment, net of tax of $51, $290, $153, and $870, respectively	146		837		439		2,511
Total Comprehensive Income	Total Comprehensive Income	$	67,227	$	63,272	$	123,083	$	110,323	Total Comprehensive Income	$	103,168	$	105,369	$	226,251	$	215,692

The accompanying notes are an integral part of these statements.

Table of Contents

Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


		June 30, 2023		December 31, 2022			September 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	$	104,455	$	108,933	Cash and cash equivalents	$	404,881	$	108,933
Receivables:	Receivables:					Receivables:
Customer (net of allowance of $3,856 and $5,034, respectively)		112,730		114,173
Other (net of allowance of $567 and $512, respectively)		56,167		50,754
Customer (net of allowance of $4,135 and $5,034, respectively)						Customer (net of allowance of $4,135 and $5,034, respectively)	135,021		114,173
Other (net of allowance of $587 and $512, respectively)						Other (net of allowance of $587 and $512, respectively)	35,887		50,754
Income taxes receivable	Income taxes receivable	—		13,108		Income taxes receivable	—		13,108
Accrued unbilled revenues	Accrued unbilled revenues	93,000		84,862		Accrued unbilled revenues	81,533		84,862
Materials and supplies (at average cost)	Materials and supplies (at average cost)	121,215		92,461		Materials and supplies (at average cost)	131,616		92,461
Fuel stock (at average cost)	Fuel stock (at average cost)	16,498		14,762		Fuel stock (at average cost)	20,950		14,762
Prepayments	Prepayments	23,703		24,396		Prepayments	22,965		24,396

Current regulatory assets	Current regulatory assets	174,848		80,049		Current regulatory assets	163,818		80,049
Other	Other	313		40,339		Other	496		40,339
Total current assets	Total current assets	702,929		623,837		Total current assets	997,167		623,837
Investments	Investments	86,096		78,791		Investments	82,232		78,791
Property, Plant and Equipment:	Property, Plant and Equipment:					Property, Plant and Equipment:
Plant in service	Plant in service	6,984,783		6,828,467		Plant in service	7,148,293		6,828,467
Accumulated provision for depreciation	Accumulated provision for depreciation	(2,544,166)		(2,465,279)		Accumulated provision for depreciation	(2,575,485)		(2,465,279)
Plant in service - net	Plant in service - net	4,440,617		4,363,188		Plant in service - net	4,572,808		4,363,188
Construction work in progress	Construction work in progress	990,181		785,706		Construction work in progress	955,276		785,706
Plant held for future use	Plant held for future use	8,860		7,130		Plant held for future use	9,491		7,130
Other property	Other property	4,316		4,558		Other property	4,313		4,558
Property, plant and equipment, net	Property, plant and equipment, net	5,443,974		5,160,582		Property, plant and equipment, net	5,541,888		5,160,582
Other Assets:	Other Assets:					Other Assets:
Company-owned life insurance	Company-owned life insurance	77,999		73,944		Company-owned life insurance	79,861		73,944
Regulatory assets	Regulatory assets	1,381,398		1,421,912		Regulatory assets	1,398,652		1,421,912
Other	Other	54,721		52,038		Other	53,201		52,038
Total other assets	Total other assets	1,514,118		1,547,894		Total other assets	1,531,714		1,547,894
Total	Total	$	7,747,117	$	7,411,104	Total	$	8,153,001	$	7,411,104

The accompanying notes are an integral part of these statements.

Table of Contents

Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


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

Current Liabilities:	Current Liabilities:					Current Liabilities:

Accounts payable	Accounts payable	$	222,977	$	292,616	Accounts payable	$	226,516	$	292,616
Accounts payable to affiliates	Accounts payable to affiliates	59,126		56,338		Accounts payable to affiliates	16,299		56,338
Taxes accrued	Taxes accrued	32,808		9,101		Taxes accrued	66,940		9,101
Interest accrued	Interest accrued	32,026		24,060		Interest accrued	21,733		24,060

Accrued compensation	Accrued compensation	47,728		58,959		Accrued compensation	53,808		58,959
Current regulatory liabilities	Current regulatory liabilities	6,405		63,957		Current regulatory liabilities	8,620		63,957
Advances from customers	Advances from customers	91,262		72,222		Advances from customers	103,860		72,222
Other	Other	34,854		26,199		Other	30,273		26,199
Total current liabilities	Total current liabilities	527,186		603,452		Total current liabilities	528,049		603,452
Other Liabilities:	Other Liabilities:					Other Liabilities:
Deferred income taxes	Deferred income taxes	858,421		870,692		Deferred income taxes	878,234		870,692
Regulatory liabilities	Regulatory liabilities	803,547		796,644		Regulatory liabilities	815,075		796,644
Pension and other postretirement benefits	Pension and other postretirement benefits	238,777		238,037		Pension and other postretirement benefits	204,604		238,037
Other	Other	122,666		76,471		Other	123,771		76,471
Total other liabilities	Total other liabilities	2,023,411		1,981,844		Total other liabilities	2,021,684		1,981,844
Long-Term Debt	Long-Term Debt	2,482,352		2,194,145		Long-Term Debt	2,826,150		2,194,145
Commitments and Contingencies	Commitments and Contingencies					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	1,918,759		1,836,547		Retained earnings	1,981,563		1,836,547
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(12,629)		(12,922)		Accumulated other comprehensive loss	(12,483)		(12,922)
Total equity	Total equity	2,714,168		2,631,663		Total equity	2,777,118		2,631,663
Total	Total	$	7,747,117	$	7,411,104	Total	$	8,153,001	$	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,					Nine months ended September 30,
		2023		2022			2023		2022
		(in thousands)					(in thousands)
Operating Activities:	Operating Activities:					Operating Activities:
Net income	Net income	$	122,790	$	108,649	Net income	$	225,812	$	213,181
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	94,382		81,053		Depreciation and amortization	146,203		126,887
Deferred income taxes and investment tax credits	Deferred income taxes and investment tax credits	(18,097)		(19,471)		Deferred income taxes and investment tax credits	(1,828)		(18,571)
Changes in regulatory assets and liabilities	Changes in regulatory assets and liabilities	(8,255)		8,658		Changes in regulatory assets and liabilities	1,585		(1,361)
Pension and postretirement benefit plan expense	Pension and postretirement benefit plan expense	13,626		14,484		Pension and postretirement benefit plan expense	20,373		21,726
Contributions to pension and postretirement benefit plans	Contributions to pension and postretirement benefit plans	(13,818)		(12,122)		Contributions to pension and postretirement benefit plans	(54,371)		(43,126)
Earnings of equity-method investments	Earnings of equity-method investments	(4,395)		(4,265)		Earnings of equity-method investments	(7,402)		(7,313)
Distributions from equity-method investments	Distributions from equity-method investments	—		4,265		Distributions from equity-method investments	550		7,313
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(21,081)		(18,410)		Allowance for equity funds used during construction	(32,125)		(27,872)
Other non-cash adjustments to net income, net	Other non-cash adjustments to net income, net	(1,665)		464		Other non-cash adjustments to net income, net	(1,056)		1,169
Change in:	Change in:					Change in:
Accounts receivable and unbilled revenues	Accounts receivable and unbilled revenues	(28,436)		(31,709)		Accounts receivable and unbilled revenues	(11,107)		(57,492)
Prepayments	Prepayments	(2,754)		754		Prepayments	(2,677)		3,353
Materials, supplies, and fuel stock	Materials, supplies, and fuel stock	(30,490)		858		Materials, supplies, and fuel stock	(45,343)		3,662
Accounts and wages payable	Accounts and wages payable	(136,183)		(23,426)		Accounts and wages payable	(156,644)		63,341
Taxes accrued/receivable	Taxes accrued/receivable	36,814		30,097		Taxes accrued/receivable	70,947		20,381
Other assets and liabilities	Other assets and liabilities	(1,837)		4,813		Other assets and liabilities	(14,844)		(11,191)
Net cash provided by operating activities	Net cash provided by operating activities	601		144,692		Net cash provided by operating activities	138,073		294,087
Investing Activities:	Investing Activities:					Investing Activities:
Additions to property, plant and equipment	Additions to property, plant and equipment	(274,162)		(193,940)		Additions to property, plant and equipment	(427,191)		(305,117)

Payments received from transmission project joint funding partners	Payments received from transmission project joint funding partners	8,953		5,531		Payments received from transmission project joint funding partners	14,920		10,979

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	—		11,287
Investments in unconsolidated affiliates		(4,900)		—

Purchases of equity securities	Purchases of equity securities	(1,576)		(27,118)		Purchases of equity securities	(2,281)		(28,063)
Purchases of held-to-maturity securities	Purchases of held-to-maturity securities	(733)		(29,692)		Purchases of held-to-maturity securities	(868)		(31,017)
Proceeds from the sale of equity securities	Proceeds from the sale of equity securities	4,401		52,833		Proceeds from the sale of equity securities	6,252		56,728

Other	Other	5,473		7,282		Other	5,996		7,407
Net cash used in investing activities	Net cash used in investing activities	(262,544)		(174,769)		Net cash used in investing activities	(403,172)		(277,796)
Financing Activities:	Financing Activities:					Financing Activities:
Issuance of long-term debt	Issuance of long-term debt	522,000		150,000		Issuance of long-term debt	872,000		150,000
Discount on issuance of long-term debt	Discount on issuance of long-term debt	(3,772)		—		Discount on issuance of long-term debt	(7,006)		—
Retirement of long-term debt	Retirement of long-term debt	(225,000)		—		Retirement of long-term debt	(225,000)		—
Dividends on common stock	Dividends on common stock	(40,625)		(76,318)		Dividends on common stock	(80,698)		(114,400)

Other	Other	4,862		(73)		Other	1,751		(138)
Net cash provided by financing activities	Net cash provided by financing activities	257,465		73,609		Net cash provided by financing activities	561,047		35,462
Net (decrease) increase in cash and cash equivalents		(4,478)		43,532
Net increase in cash and cash equivalents						Net increase in cash and cash equivalents	295,948		51,753
Cash and cash equivalents at beginning of the period	Cash and cash equivalents at beginning of the period	108,933		60,075		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	$	104,455	$	103,607	Cash and cash equivalents at end of the period	$	404,881	$	111,828
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	Cash paid to IDACORP related to income taxes	$	15,333	$	2,532
Cash paid for interest (net of amount capitalized)	Cash paid for interest (net of amount capitalized)	$	43,767	$	41,647	Cash paid for interest (net of amount capitalized)	$	82,372	$	67,806
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	$	137,717	$	70,063	Additions to property, plant and equipment in accounts payable	$	127,076	$	65,374

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).~~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.~~FERC. Idaho Power is the parent of ~~Idaho Energy Resources Co. (IERCo),~~IERCo, a joint venturer in ~~Bridger Coal Company (BCC),~~BCC, which mines and supplies coal to the Jim Bridger ~~power~~ plant ~~(Jim Bridger plant)~~ owned in part by Idaho Power.

IDACORP’s other notable wholly-owned subsidiaries include ~~IDACORP Financial Services, Inc. (IFS),~~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).~~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 balance sheets as of ~~June~~September 30, 2023, condensed consolidated statements of income for the three months and ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, and condensed consolidated cash flows for the ~~six~~nine months ended ~~June~~September 30, 2023 and 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~~the 2022 Annual ~~Report on Form 10-K for the year ended December 31, 2022 (2022 Annual Report).~~Report. The statements of 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 balance sheets and statements of 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 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

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liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting

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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~~nine months ended ~~June~~September 30, 2023 and 2022 (in thousands):


		IDACORP						Idaho Power							IDACORP						Idaho Power
		2023			2022			2023			2022				2023			2022			2023			2022
Income tax at statutory rates (federal and state)	Income tax at statutory rates (federal and state)	$	36,010		$	32,140		$	35,697		$	32,088		Income tax at statutory rates (federal and state)	$	66,650		$	63,500		$	65,916		$	62,960
Additional accumulated deferred investment tax credits (ADITC) amortization		(7,500)			—			(7,500)			—
Additional ADITC amortization														Additional ADITC amortization	(7,500)			—			(7,500)			—

Excess deferred income tax reversal	Excess deferred income tax reversal	(5,342)			(5,703)			(5,342)			(5,703)			Excess deferred income tax reversal	(8,013)			(8,554)			(8,013)			(8,554)

Income tax return adjustments														Income tax return adjustments	(8,227)			(2,692)			(7,732)			(2,827)
Other(1)	Other(1)	(7,942)			(12,120)			(6,961)			(10,372)			Other(1)	(13,910)			(22,486)			(12,397)			(20,161)
Income tax expense	Income tax expense	$	15,226		$	14,317		$	15,894		$	16,013		Income tax expense	$	29,000		$	29,768		$	30,274		$	31,418
Effective tax rate	Effective tax rate	10.9		%	11.5		%	11.5		%	12.8		%	Effective tax rate	11.2		%	12.1		%	11.8		%	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)~~IPUC and ~~Public Utility Commission of Oregon (OPUC)~~OPUC orders described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2022 Annual Report.

On June 1, 2023, Idaho Power filed a general rate case with the IPUC. The filing iswas based on a 2023 test year and ~~requests~~requested approximately $111 million in additional Idaho jurisdiction annual revenues, which is net of a corresponding proposed ~~power cost adjustment (PCA)~~PCA decrease of $173.4 million and a reduction to annual energy efficiency rider collection of $3.5 million. ~~If approved,~~As filed, this request would ~~result~~have resulted in an 8.61 percent overall average net ~~base~~ rate increase for Idaho Power's Idaho customers. The filing ~~requests,~~requested, 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.

On October 27, 2023, Idaho Power, the Staff of the IPUC, and intervening parties publicly filed a settlement stipulation (2023 General Rate Case Settlement Stipulation) with the IPUC related to the Idaho general rate case filing. If the IPUC approves the

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~~In addition,~~2023 General Rate Case Settlement Stipulation, it will authorize Idaho Power's filed general rate case, with the modifications contained in the 2023 General Rate Case Settlement Stipulation.

As modified by the proposed 2023 General Rate Case Settlement Stipulation, Idaho Power’s general rate case filing ~~requests approval or authorization of,~~contains the following significant terms, among other items:

•Idaho Power would implement revised tariff schedules designed to increase annual Idaho-jurisdictional retail revenue by $54.7 million, or 4.25 percent, effective January 1, 2024. The $54.7 million of additional annual revenue is net of a PCA rate decrease of $168.3 million (moving that amount from collection via the PCA and into base rates) and a reduction to annual energy efficiency rider collection of $3.5 million.

•A 9.6 percent return on equity and a 7.247 percent authorized rate of return based on a non-specified cost of debt and capital structure, applied to an Idaho-jurisdictional rate base of approximately $3.8 billion.

•Modifications to the Idaho-jurisdiction PCA including establishment of a new level of base net power ~~cost adjustment (PCA) necessary to support~~supply expense of $484.9 million, which includes the transfer of ~~certain base level net power supply costs~~$168.3 million from ~~the~~current PCA rates to base rates;

•Modifications to the energy efficiency rider to support the transfer of $3.5 million of energy efficiency labor-related cost collection from the annual energy efficiency rider into base ~~rates;~~rates, warranting a decrease in the energy efficiency rider rate from 3.1 percent to 2.35 percent;

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

•Continued deferral of incremental vegetation management and insurance costs, ~~in 2024 and beyond~~ as measured from ~~a new base level~~2022 actual costs, through the earlier of ~~costs established in the~~Idaho Power’s next Idaho general rate ~~case;~~case or 2025;

•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,~~Modifications to ~~(1) move an estimated $45 million of investment tax credits, including from certain battery storage projects, to the existing~~Idaho Power’s ADITC and revenue sharing mechanism ~~described in more detail below, and (2) increase the existing $25 million maximum allowed annual~~(1) to include an additional ~~accelerated ADITC amortization amount under the mechanism by a dollar~~ amount of investment tax credits equal to the ~~actual revenue requirement of those~~incremental investment tax credits generated from Idaho Power’s investment in 2023 battery storage ~~projects in any applicable year;~~projects; (2) to remove the existing $25 million annual cap on the amount of accelerated amortization of ADITCs; (3) to establish a minimum specified Idaho ROE of 9.12 percent for additional amortization of ADITCs; (4) to establish a 9.6 percent Idaho ROE as the threshold for revenue sharing of Idaho-jurisdiction earnings between Idaho Power and Idaho customers; and (5) to implement all revenue sharing through the PCA rather than a portion offsetting customer-funded pension obligations;

•Agreement that Idaho Power’s share of capital expenditures at jointly-owned coal-fired plants through year-end 2022 was prudently incurred;

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

•~~A proposed~~Modifications to the residential price modernization ~~plan.~~plan proposed by Idaho Power in its initial filing, as well as other modifications to Idaho Power’s proposed rate design.

The 2023 General Rate Case Settlement Stipulation further provides for future workshops and discussions among the parties on time-of-use rates and other unresolved topics and further review of Idaho Power plant investments by IPUC Staff to be completed by December 1, 2023. To the extent IPUC Staff identifies potential prudence concerns, those prudence concerns would be addressed in Idaho Power's next general rate case.

The parties to the 2023 General Rate Case Settlement Stipulation have requested that the IPUC issue an order approving the agreed-upon rates effective January 1, 2024. The 2023 General Rate Case Settlement Stipulation does not preclude Idaho Power from filing another general rate case in Idaho at any time in the future. If the IPUC were to deny the 2023 General Rate Case Settlement Stipulation or materially change its terms, no party would be bound by the terms of the stipulation. As of the date of this report, ~~Idaho Power~~the IPUC's determination in this matter 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.~~pending.

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Idaho ~~Settlement Stipulations~~ADITC and Revenue Sharing Mechanism

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 2022 Annual Report and includes provisions for the accelerated amortization of ADITC to help achieve a minimum 9.4 percent ~~Idaho-jurisdiction return on year-end equity (Idaho ROE).~~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 Idaho ROE, which would adjust to the authorized return on equity in the next general rate case currently pending before the IPUC.

Based on its estimate of full-year 2023 Idaho ROE, in the three and ~~six~~nine months ended ~~June~~September 30, 2023, Idaho Power recorded ~~$3.8 million~~zero and $7.5 million, respectively, for additional ADITC amortization 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~~September 30, 2023, $37.5 million of additional ADITC remains available for future use. Idaho Power recorded no additional ADITC amortization or provision against revenues for sharing of earnings with customers during 2022.

If approved by the IPUC, the 2023 General Rate Case Settlement Stipulation would modify the Idaho ADITC and revenue sharing mechanism as noted above.

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 2023, the IPUC issued an order approving recovery of an incremental $200.2 million of 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 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, effective for the PCA collection period from June 1, 2023, to May 31, 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 higher market energy and natural gas 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 net increase also reflects an expectation of continued elevated market energy and natural gas prices in the April 2023 to March 2024 forecast period under the PCA. If approved by the IPUC, the 2023 General Rate Case Settlement Stipulation would modify the PCA mechanism as noted above.

In May 2023, the OPUC issued an order approving Idaho 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 FCA mechanism, applicable to Idaho residential and small 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)~~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 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 2023, the IPUC issued an order approving a $10.1 million decrease in recovery from the FCA from $35.2 million to $25.1 million for the 2022 FCA deferral, with new rates effective for the period from June 1, 2023, to May 31, 2024. Beginning with the 2024 FCA deferral, if approved by the IPUC, the 2023 General Rate Case Settlement

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Stipulation would update the authorized fixed-cost recovery amount per customer and would modify parts of the FCA mechanism to support Idaho Power's proposed rate designs, as noted above.

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 (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, (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 (3) increase customer rates related to 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)~~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,~~the 2023 ~~general rate case filing with the IPUC.~~General Rate Case Settlement Stipulation. 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. 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.

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).~~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 IPUC, Idaho Power projected spending approximately $47 million in incremental wildfire mitigation-related O&M and roughly $35 million in wildfire mitigation system-hardening incremental capital 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~~September 30, 2023, Idaho Power's deferral of Idaho-jurisdiction costs related to the WMP was ~~$39.5~~$45.4 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. As noted above, if approved by the IPUC, the 2023 General Rate Case Settlement Stipulation would allow continued deferral of incremental vegetation management and insurance costs, as measured from 2022 actual costs, through the earlier of Idaho Power’s next Idaho general rate case or 2025.

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4. REVENUES

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Revenue from contracts with customers	Revenue from contracts with customers	$	385,229	$	345,483	$	770,895	$	663,665	Revenue from contracts with customers	$	496,632	$	515,395	$	1,267,527	$	1,179,059
Alternative revenue programs and other revenues	Alternative revenue programs and other revenues	27,498		12,185		71,170		37,924		Alternative revenue programs and other revenues	13,003		1,706		84,173		39,631
Total electric utility operating revenues	Total electric utility operating revenues	$	412,727	$	357,668	$	842,065	$	701,589	Total electric utility operating revenues	$	509,635	$	517,101	$	1,351,700	$	1,218,690

Revenues from Contracts with Customers

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Retail revenues:	Retail revenues:									Retail revenues:
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)		87,677		79,260		175,507		157,826
Residential (includes $5,583, $(1,447), $20,170, and $14,104, respectively, related to the FCA)(1)										Residential (includes $5,583, $(1,447), $20,170, and $14,104, respectively, related to the FCA)(1)	$	181,736	$	176,514	$	505,158	$	470,402
Commercial (includes $328, $142, $900, and $730, respectively, related to the FCA)(1)										Commercial (includes $328, $142, $900, and $730, respectively, related to the FCA)(1)	107,971		101,794		283,478		259,620
Industrial	Industrial	58,245		51,987		113,789		101,047		Industrial	67,522		60,306		181,312		161,353
Irrigation	Irrigation	62,781		57,659		63,713		58,700		Irrigation	104,645		105,365		168,358		164,065

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)	(2,815)		(2,815)		(6,861)		(6,861)

Total retail revenues	Total retail revenues	341,661		311,572		672,385		607,415		Total retail revenues	459,059		441,164		1,131,445		1,048,579
Less: FCA mechanism revenues(1)	Less: FCA mechanism revenues(1)	(5,974)		(5,763)		(15,159)		(16,139)		Less: FCA mechanism revenues(1)	(5,911)		1,305		(21,070)		(14,834)
Wholesale energy sales	Wholesale energy sales	15,201		6,980		45,397		10,015		Wholesale energy sales	5,065		34,501		50,461		44,516
Transmission wheeling-related revenues	Transmission wheeling-related revenues	20,026		18,323		41,611		34,788		Transmission wheeling-related revenues	20,090		22,882		61,701		57,670
Energy efficiency program revenues	Energy efficiency program revenues	6,552		6,609		11,767		13,198		Energy efficiency program revenues	10,498		8,292		22,265		21,490
Other revenues from contracts with customers	Other revenues from contracts with customers	7,763		7,762		14,894		14,388		Other revenues from contracts with customers	7,831		7,251		22,725		21,638
Total revenues from contracts with customers	Total revenues from contracts with customers	$	385,229	$	345,483	$	770,895	$	663,665	Total revenues from contracts with customers	$	496,632	$	515,395	$	1,267,527	$	1,179,059

(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)~~AFUDC on construction work in progress related to the ~~Hells Canyon Complex (HCC)~~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 11 - "Derivative Financial Instruments."

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
FCA mechanism revenues	FCA mechanism revenues	$	5,974	$	5,763	$	15,159	$	16,139	FCA mechanism revenues	$	5,911	$	(1,305)	$	21,070	$	14,834
Derivative revenues	Derivative revenues	21,524		6,422		56,011		21,785		Derivative revenues	7,092		3,011		63,103		24,797
Total alternative revenue programs and other revenues	Total alternative revenue programs and other revenues	$	27,498	$	12,185	$	71,170	$	37,924	Total alternative revenue programs and other revenues	$	13,003	$	1,706	$	84,173	$	39,631

Receivables and Allowance for Uncollectible Accounts

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


		Six months ended June 30,							Nine months ended September 30,
		2023			2022				2023			2022
Balance at beginning of period	Balance at beginning of period	$	5,034		$	4,499		Balance at beginning of period	$	5,034		$	4,499
Additions to the allowance	Additions to the allowance	739			478			Additions to the allowance	2,040			1,785
Write-offs, net of recoveries	Write-offs, net of recoveries	(1,917)			(1,056)			Write-offs, net of recoveries	(2,939)			(1,631)
Balance at end of period	Balance at end of period	$	3,856		$	3,921		Balance at end of period	$	4,135		$	4,653
Allowance for uncollectible accounts as a percentage of customer receivables	Allowance for uncollectible accounts as a percentage of customer receivables	3.3		%	4.3		%	Allowance for uncollectible accounts as a percentage of customer receivables	3.0		%	3.5		%

5. LONG-TERM DEBT

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 September 11, 2023, under the shelf registration statement with the SEC, Idaho Power issued $350 million in aggregate principal amount of 5.80% first mortgage bonds, secured medium-term notes, Series M, maturing on April 1, 2054.

On March 4, 2022, Idaho Power entered into a floating rate term loan credit agreement (Term Loan Facility) for the issuance of up to an aggregate principal amount of $150 million 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 the Term Loan Facility, respectively. As of ~~June~~September 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~~nine months ended ~~June~~September 30, 2023, IDACORP granted 75,295 restricted stock unit awards to employees and issued ~~52,897~~53,345 shares of common stock using original issuances of shares pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan, including 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.

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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 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~~September 30, 2023, the leverage ratios for IDACORP and Idaho Power were 4749 percent and 4850 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to ~~$1.5~~$1.4 billion and ~~$1.4~~$1.3 billion, respectively, at ~~June~~September 30, 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~~September 30, 2023, IDACORP and Idaho Power were in compliance with those 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~~September 30, 2023, Idaho Power's common equity capital was 5250 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~~nine months ended ~~June~~September 30, 2023 and 2022 (in thousands, except for per share amounts).


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Numerator:	Numerator:									Numerator:
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548	Net income attributable to IDACORP, Inc.	$	105,264	$	106,380	$	229,936	$	216,928
Denominator:	Denominator:									Denominator:
Weighted-average common shares outstanding - basic	Weighted-average common shares outstanding - basic	50,725		50,668		50,707		50,650		Weighted-average common shares outstanding - basic	50,726		50,668		50,713		50,656
Effect of dilutive securities	Effect of dilutive securities	33		19		34		23		Effect of dilutive securities	79		54		49		33
Weighted-average common shares outstanding - diluted	Weighted-average common shares outstanding - diluted	50,758		50,687		50,741		50,673		Weighted-average common shares outstanding - diluted	50,805		50,722		50,762		50,689
Basic earnings per share	Basic earnings per share	$	1.35	$	1.27	$	2.46	$	2.18	Basic earnings per share	$	2.08	$	2.10	$	4.53	$	4.28
Diluted earnings per share	Diluted earnings per share	$	1.35	$	1.27	$	2.46	$	2.18	Diluted earnings per share	$	2.07	$	2.10	$	4.53	$	4.28

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8. COMMITMENTS

Purchase Obligations

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

•an agreement in April 2023 to utilize the storage capacity of a ~~150-megawatt (MW)~~150 MW battery storage facility, ~~subject to regulatory approval,~~ which increased Idaho Power's contractual purchase obligations by approximately $430.9 million over the 20-year term of the contract. The facility is scheduled to be online in June 2025;

•an agreement in May 2023 to replace an expiring PURPA-qualifying hydropower facility power purchase agreement, which increased Idaho Power's contractual purchase obligations by approximately $29.1 million over the 20-year term of the contract;

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•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 term of the contract. The batteries are scheduled to be online in the spring of 2024. During the ~~six~~nine months ended ~~June~~September 30, 2023, Idaho Power made payments of ~~$10.5~~$11.1 million related to this ~~obligation.~~obligation; and

•

Inan agreement 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.During the nine months ended September 30, 2023, Idaho Power made payments of $3 million related to this obligation.

In July 2023, IFS committed to invest $35 million in an affordable housing tax credit project over an 18-year term. During the nine months ended September 30, 2023, IFS made $5.7 million in capital contributions toward this commitment.

In October 2023, Idaho Power entered into two new contracts to acquire and own 82 MW of battery storage assets, which collectively increase Idaho Power's contractual purchase obligations by approximately $87.1 million over the approximate 2-year terms of the contracts.

Except as disclosed in this Note 8, during the ~~six~~nine months ended ~~June~~September 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 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)~~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 $47.3 million at ~~June~~September 30, 2023, representing IERCo's one-third share of BCC's total reclamation obligation of $141.9 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At ~~June~~September 30, 2023, the value of BCC's reclamation trust fund was ~~$226.2~~$227.1 million. During the ~~six~~nine months ended ~~June~~September 30, 2023, the reclamation trust fund made ~~$2.2~~$3.8 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 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~~September 30, 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.

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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 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~~Idaho Power’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, 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).~~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~~September 30, 2023 and 2022 (in thousands).


		Pension Plan				SMSP				Postretirement Benefits				Total					Pension Plan				SMSP				Postretirement Benefits				Total
		2023		2022		2023		2022		2023		2022		2023		2022			2023		2022		2023		2022		2023		2022		2023		2022
Service cost	Service cost	$	8,078	$	12,849	$	153	$	297	$	151	$	266	$	8,382	$	13,412	Service cost	$	6,549	$	13,006	$	153	$	296	$	165	$	267	$	6,867	$	13,569
Interest cost	Interest cost	12,655		9,751		1,330		975		717		530		14,702		11,256		Interest cost	13,149		9,918		1,331		974		745		528		15,225		11,420
Expected return on plan assets	Expected return on plan assets	(15,434)		(18,137)		—		—		(407)		(585)		(15,841)		(18,722)		Expected return on plan assets	(15,303)		(18,087)		—		—		(412)		(587)		(15,715)		(18,674)
Amortization of prior service cost	Amortization of prior service cost	1		1		55		69		417		(2)		473		68		Amortization of prior service cost	2		1		54		70		416		(1)		472		70
Amortization of net loss	Amortization of net loss	—		2,589		143		1,058		(346)		(5)		(203)		3,642		Amortization of net loss	—		3,068		143		1,057		(310)		(7)		(167)		4,118
Net periodic benefit cost	Net periodic benefit cost	5,300		7,053		1,681		2,399		532		204		7,513		9,656		Net periodic benefit cost	4,397		7,906		1,681		2,397		604		200		6,682		10,503
Regulatory deferral of net periodic benefit cost(1)	Regulatory deferral of net periodic benefit cost(1)	(5,061)		(6,727)		—		—		—		—		(5,061)		(6,727)		Regulatory deferral of net periodic benefit cost(1)	(4,223)		(7,549)		—		—		—		—		(4,223)		(7,549)
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)	4,288		4,288		—		—		—		—		4,288		4,288
Net periodic benefit cost recognized for financial reporting(1)(2)	Net periodic benefit cost recognized for financial reporting(1)(2)	$	4,528	$	4,615	$	1,681	$	2,399	$	532	$	204	$	6,741	$	7,218	Net periodic benefit cost recognized for financial reporting(1)(2)	$	4,462	$	4,645	$	1,681	$	2,397	$	604	$	200	$	6,747	$	7,242

(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, $5.1 million and ~~$5.0~~$4.9 million, respectively, were recognized in "Other operations and maintenance" and ~~$1.6~~$1.7 million and ~~$2.2~~$2.3 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the three months ended ~~June~~September 30, 2023 and 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, 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 nine months ended September 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 nine months ended September 30, 2023 and 2022 (in thousands).
		Pension Plan				SMSP				Postretirement Benefits				Total					Pension Plan				SMSP				Postretirement Benefits				Total
		2023		2022		2023		2022		2023		2022		2023		2022			2023		2022		2023		2022		2023		2022		2023		2022
Service cost	Service cost	$	16,156	$	26,013	$	306	$	593	$	329	$	536	$	16,791	$	27,142	Service cost	$	22,705	$	39,019	$	459	$	889	$	494	$	803	$	23,658	$	40,711
Interest cost	Interest cost	25,309		19,835		2,661		1,949		1,490		1,056		29,460		22,840		Interest cost	38,458		29,753		3,992		2,923		2,235		1,584		44,685		34,260
Expected return on plan assets	Expected return on plan assets	(30,868)		(36,174)		—		—		(826)		(1,176)		(31,694)		(37,350)		Expected return on plan assets	(46,171)		(54,261)		—		—		(1,238)		(1,763)		(47,409)		(56,024)
Amortization of prior service cost	Amortization of prior service cost	3		3		110		139		833		(3)		946		139		Amortization of prior service cost	5		5		164		209		1,249		(4)		1,418		210
Amortization of net loss	Amortization of net loss	—		6,137		285		2,115		(618)		(16)		(333)		8,236		Amortization of net loss	—		9,205		428		3,172		(928)		(23)		(500)		12,354
Net periodic benefit cost	Net periodic benefit cost	10,600		15,814		3,362		4,796		1,208		397		15,170		21,007		Net periodic benefit cost	14,997		23,721		5,043		7,193		1,812		597		21,852		31,511
Regulatory deferral of net periodic benefit cost(1)	Regulatory deferral of net periodic benefit cost(1)	(10,121)		(15,100)		—		—		—		—		(10,121)		(15,100)		Regulatory deferral of net periodic benefit cost(1)	(14,344)		(22,650)		—		—		—		—		(14,344)		(22,650)
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)	12,865		12,865		—		—		—		—		12,865		12,865
Net periodic benefit cost recognized for financial reporting(1)(2)	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	Net periodic benefit cost recognized for financial reporting(1)(2)	$	13,518	$	13,936	$	5,043	$	7,193	$	1,812	$	597	$	20,373	$	21,726

(2) Of total net periodic benefit cost recognized for financial reporting, ~~$10.4~~$15.5 million and ~~$9.9~~$14.8 million, respectively, were recognized in "Other operations and maintenance" and ~~$3.2~~$4.9 million and ~~$4.6~~$6.9 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022.

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in 2023, and during the ~~six~~nine months ended ~~June~~September 30, 2023, Idaho Power ~~made a $10~~contributed $48 million ~~contribution. Idaho Power is considering contributing up to an additional $30 million to 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, as well as to mitigate the cost of being in an underfunded position. 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.

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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

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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~~nine months ended ~~June~~September 30, 2023 and 2022 (in 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 September 30,						Nine months ended September 30,
			2023		2022			2023			2022							2023		2022			2023			2022
Financial swaps	Financial swaps		Operating revenues		$	5,042		$	(1,577)		$	3,963		$	(995)	Financial swaps		Operating revenues		$	253		$	(3,763)		$	4,216		$	(4,758)
Financial swaps	Financial swaps	Purchased power		(1,733)			(1,197)			(107)			(1,081)	Financial swaps			Purchased power		(8,541)			3,038			(8,647)			1,957
Financial swaps	Financial swaps	Fuel expense		(11,422)			2,991			12,114			4,451	Financial swaps			Fuel expense		(7,932)			24,178			4,182			28,629

Forward contracts	Forward contracts	Operating revenues		1,075			32			1,710			211	Forward contracts			Operating revenues		—			502			1,710			713
Forward contracts	Forward contracts	Purchased power		(1,449)			(31)			(2,049)			(210)	Forward contracts			Purchased power		(1,454)			(2,430)			(3,504)			(2,640)
Forward contracts	Forward contracts	Fuel expense		(19)			(9)			(439)			(62)	Forward contracts			Fuel expense		(202)			(207)			(641)			(269)

(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 12 - "Fair Value Measurements" for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.

Credit Risk

At ~~June~~September 30, 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 usually under 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'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.~~S&P Global Ratings. 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. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position at ~~June~~September 30, 2023, was ~~$33.7~~$25.0 million. Idaho Power posted ~~$44.4~~$29.1 million of cash collateral

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related to its derivative instruments. If the credit-risk-related contingent features underlying these agreements were triggered on ~~June~~September 30, 2023, Idaho Power would have been required to pay or post collateral to its counterparties up to an additional ~~$9.2~~$5.4 million to cover 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~~September 30, 2023, and December 31, 2022 (in 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, 2023
September 30, 2023																	September 30, 2023
Current:	Current:																Current:
Financial swaps	Financial swaps	Other current assets	$	344	$	(31)		$	313	$	31	$	(31)		$	—	Financial swaps	Other current assets	$	811	$	(315)		$	496	$	315	$	(315)		$	—
Financial swaps	Financial swaps	Other current liabilities	4,110		(4,110)			—		27,897		(21,648)		(1)	6,249		Financial swaps	Other current liabilities	2,668		(2,668)			—		22,108		(21,778)		(1)	330

Forward contracts	Forward contracts	Other current liabilities	—		—			—		2,066		—			2,066		Forward contracts	Other current liabilities	—		—			—		1,808		—			1,808
Long-term:	Long-term:																Long-term:
Financial swaps	Financial swaps	Other assets	688		(348)			340		348		(348)			—		Financial swaps	Other assets	141		(90)			51		90		(90)			—
Financial swaps	Financial swaps	Other liabilities	371		(371)			—		2,075		(2,075)		(2)	—		Financial swaps	Other liabilities	522		(522)			—		632		(632)		(2)	—
Forward contracts		Other liabilities	—		—			—		1,363		—			1,363

Total	Total		$	5,513	$	(4,860)		$	653	$	33,780	$	(24,102)		$	9,678	Total		$	4,142	$	(3,595)		$	547	$	24,953	$	(22,815)		$	2,138

December 31, 2022	December 31, 2022																December 31, 2022
Current:	Current:																Current:
Financial swaps	Financial swaps	Other current assets	$	72,548	$	(32,609)	(3)	$	39,939	$	13,982	$	(13,982)		$	—	Financial swaps	Other current assets	$	72,548	$	(32,609)	(3)	$	39,939	$	13,982	$	(13,982)		$	—
Financial swaps	Financial swaps	Other current liabilities	132		(132)			—		1,577		(132)			1,445		Financial swaps	Other current liabilities	132		(132)			—		1,577		(132)			1,445
Forward contracts	Forward contracts	Other current assets	400		—			400		—		—			—		Forward contracts	Other current assets	400		—			400		—		—			—
Forward contracts	Forward contracts	Other current liabilities	—		—			—		2,071		—			2,071		Forward contracts	Other current liabilities	—		—			—		2,071		—			2,071
Long-term:	Long-term:																Long-term:
Financial swaps	Financial swaps	Other assets	622		(43)			579		43		(43)			—		Financial swaps	Other assets	622		(43)			579		43		(43)			—
Financial swaps	Financial swaps	Other liabilities	644		(644)			—		2,136		(644)			1,492		Financial swaps	Other liabilities	644		(644)			—		2,136		(644)			1,492
Forward contracts	Forward contracts	Other liabilities	—		—			—		1,780		—			1,780		Forward contracts	Other liabilities	—		—			—		1,780		—			1,780
Total	Total		$	74,346	$	(33,428)		$	40,918	$	21,589	$	(14,801)		$	6,788	Total		$	74,346	$	(33,428)		$	40,918	$	21,589	$	(14,801)		$	6,788

(1) Current liability derivative amounts offset include ~~$17.5~~$19.1 million of collateral receivable at ~~June~~September 30, 2023.

(2) Long-term liability derivative amounts offset include ~~$1.7 million~~$110 thousand of collateral receivable at ~~June~~September 30, 2023.

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

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


			June 30,				September 30,
Commodity	Commodity	Units	2023	2022	Commodity	Units	2023	2022
Electricity purchases	Electricity purchases	MWh	792	541	Electricity purchases	MWh	434	344
Electricity sales	Electricity sales	MWh	17	118	Electricity sales	MWh	—	72
Natural gas purchases	Natural gas purchases	MMBtu	35,545	21,215	Natural gas purchases	MMBtu	27,283	14,958
Natural gas sales		MMBtu	310	—

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

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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 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~~nine months ended ~~June~~September 30, 2023.

Certain instruments have been valued using ~~net asset value (NAV)~~NAV as a practical expedient. 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 presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of ~~June~~September 30, 2023, and December 31, 2022 (in thousands of dollars).


		June 30, 2023								December 31, 2022									September 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 and commercial paper	Money market funds and commercial paper																	Money market funds and commercial paper
IDACORP(1)	IDACORP(1)	$	7,998	$	—	$	—	$	7,998	$	16,505	$	—	$	—	$	16,505	IDACORP(1)	$	16,846	$	—	$	—	$	16,846	$	16,505	$	—	$	—	$	16,505
Idaho Power	Idaho Power	43,909		—		—		43,909		34,468		—		—		34,468		Idaho Power	360,343		—		—		360,343		34,468		—		—		34,468
Derivatives	Derivatives	653		—		—		653		40,518		400		—		40,918		Derivatives	547		—		—		547		40,518		400		—		40,918
Equity securities	Equity securities	31,617		—		—		31,617		34,129		—		—		34,129		Equity securities	30,157		—		—		30,157		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)	—		—		—		3,236		—		—		—		2,796		IDACORP assets measured at NAV (not subject to hierarchy disclosure)(1)	—		—		—		3,852		—		—		—		2,796
Liabilities:	Liabilities:																	Liabilities:
Derivatives	Derivatives	6,249		3,429		—		9,678		2,937		3,851		—		6,788		Derivatives	$	330	$	1,808	$	—	$	2,138	$	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

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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~~September 30, 2023, and December 31, 2022, using available market information and appropriate valuation methodologies (in thousands of dollars).


		June 30, 2023				December 31, 2022					September 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)	$	3,871	$	3,871	$	3,871	$	3,871	Notes receivable(1)	$	3,871	$	3,871	$	3,871	$	3,871
Held-to-maturity securities(1)(2)	Held-to-maturity securities(1)(2)	30,996		26,499		30,475		25,452		Held-to-maturity securities(1)(2)	31,035		26,024		30,475		25,452
Liabilities:	Liabilities:									Liabilities:
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		Long-term debt (including current portion)(1)	2,826,150		2,434,357		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)	$	30,996	$	26,499	$	30,475	$	25,452	Held-to-maturity securities(1)(2)	$	31,035	$	26,024	$	30,475	$	25,452
Liabilities:	Liabilities:									Liabilities:
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		Long-term debt (including current portion)(1)	2,826,150		2,434,357		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 12 - "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~~both September 30, 2023, and December 31, ~~2022, respectively.~~2022. 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~~September 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. 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.

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.

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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 September 30, 2023:										Three months ended September 30, 2023:
Revenues	Revenues	$	412,727	$	1,111	$	—	$	413,838	Revenues	$	509,635	$	1,271	$	—	$	510,906
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	67,080		1,494		—		68,574		Net income attributable to IDACORP, Inc.	103,022		2,242		—		105,264
Total assets as of June 30, 2023		7,747,117		211,650		(119,699)		7,839,068
Three months ended June 30, 2022:
Total assets as of September 30, 2023										Total assets as of September 30, 2023	8,153,001		213,833		(73,300)		8,293,534
Three months ended September 30, 2022:										Three months ended September 30, 2022:
Revenues	Revenues	$	357,668	$	1,055	$	—	$	358,723	Revenues	$	517,101	$	911	$	—	$	518,012
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	62,435		1,852		—		64,287		Net income attributable to IDACORP, Inc.	104,532		1,848		—		106,380
Six months ended June 30, 2023:
Nine months ended September 30, 2023:										Nine months ended September 30, 2023:
Revenues	Revenues	$	842,065	$	1,432	$	—	$	843,497	Revenues	$	1,351,700	$	2,703	$	—	$	1,354,403
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	122,790		1,882		—		124,672		Net income attributable to IDACORP, Inc.	225,812		4,124		—		229,936
Six months ended June 30, 2022:
Nine months ended September 30, 2022:										Nine months ended September 30, 2022:
Revenues	Revenues	$	701,589	$	1,422	$	—	$	703,011	Revenues	$	1,218,690	$	2,333	$	—	$	1,221,023
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	108,649		1,899		—		110,548		Net income attributable to IDACORP, Inc.	213,181		3,747		—		216,928

14. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

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

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

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	Defined Benefit Pension Items				Defined Benefit Pension Items
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Balance at beginning of period	$	(12,629)	$	(38,366)	$	(12,922)	$	(40,040)
Amounts reclassified out of AOCI	146		837		439		2,511
Balance at end of period	$	(12,483)	$	(37,529)	$	(12,483)	$	(37,529)

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~~nine months ended ~~June~~September 30, 2023 and 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 September 30,				Nine months ended September 30,
		2023		2022		2023		2022			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	$	55	$	69	$	110	$	139	Prior service cost	$	54	$	70	$	164	$	209
Net loss	Net loss	143		1,058		285		2,115		Net loss	143		1,057		428		3,172
Total before tax	Total before tax	198		1,127		395		2,254		Total before tax	197		1,127		592		3,381
Tax benefit(2)	Tax benefit(2)	(51)		(290)		(102)		(580)		Tax benefit(2)	(51)		(290)		(153)		(870)

Total reclassification for the period, net of tax	Total reclassification for the period, net of tax	$	147	$	837	$	293	$	1,674	Total reclassification for the period, net of tax	$	146	$	837	$	439	$	2,511

(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.

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15. CHANGES IN IDAHO POWER RETAINED EARNINGS

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Balance at beginning of period	Balance at beginning of period	$	1,891,898	$	1,704,320	$	1,836,547	$	1,696,304	Balance at beginning of period	$	1,918,759	$	1,728,635	$	1,836,547	$	1,696,304
Net income	Net income	67,080		62,435		122,790		108,649		Net income	103,022		104,532		225,812		213,181
Dividends to parent	Dividends to parent	(40,219)		(38,120)		(40,578)		(76,318)		Dividends to parent	(40,218)		(38,124)		(80,796)		(114,442)
Balance at end of period	Balance at end of period	$	1,918,759	$	1,728,635	$	1,918,759	$	1,728,635	Balance at end of period	$	1,981,563	$	1,795,043	$	1,981,563	$	1,795,043

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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~~September 30, 2023, the related condensed consolidated statements of income, comprehensive income, and equity for the three-month and ~~six-month~~nine-month periods ended ~~June~~September 30, 2023 and 2022, and of cash flows for the ~~six-month~~nine-month periods ended ~~June~~September 30, 2023 and 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, 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 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, 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 3,~~November 2, 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~~September 30, 2023, the related condensed consolidated statements of income and comprehensive income for the three-month and ~~six-month~~nine-month periods ended ~~June~~September 30, 2023 and 2022, and of cash flows for the ~~six-month~~nine-month periods ended ~~June~~September 30, 2023 and 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, 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 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, 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 3,~~November 2, 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)~~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~~the 2022 Annual Report, ~~on Form 10-K for the year ended December 31, 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),~~IPUC, OPUC, and ~~Federal Energy Regulatory Commission (FERC).~~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),~~IERCo, a joint venturer in ~~Bridger Coal Company (BCC),~~BCC, which mines and supplies coal to the Jim Bridger ~~power~~ plant ~~(Jim Bridger plant)~~ owned in part by Idaho Power. IDACORP’s other ~~significant~~notable subsidiaries include ~~IDACORP Financial Services, Inc.,~~IFS, 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).~~PURPA.

EXECUTIVE OVERVIEW

Management's Outlook and Company Objectives

In the 2022 Annual Report, IDACORP's and Idaho Power's management included a summary of their business objectives for the companies for 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. Developments that have occurred since that report include the following:

•Idaho Power continues to focus on timely recovery of costs and earning a reasonable return on investment. On ~~June 1,~~October 27, 2023, Idaho Power, the Staff of the IPUC, and intervening parties publicly filed a settlement stipulation (2023 General Rate Case Settlement Stipulation) with the IPUC related to the Idaho general rate case ~~with~~that Idaho Power had filed on June 1, 2023. The 2023 General Rate Case Settlement Stipulation is subject to approval by the IPUC. The general rate case filing isand 2023 General Rate Case Settlement Stipulation are described more fully in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report.

•In September 2023, Idaho Power filed its 2023 IRP with the IPUC and OPUC. The 2023 IRP preferred resource portfolio plans for a significant increase in energy and capacity resources over the next 20 years to meet growing demand, primarily solar, wind, and battery resource additions. In addition, the preferred resource portfolio includes conversions of multiple jointly-owned coal-fired generation units to natural gas-fired generation units. To support the resource additions, the preferred portfolio also includes the Boardman-to-Hemingway transmission line with an in-service date as early as 2026 and three Gateway West transmission line segments phased in with in-service dates from 2028 through 2040.

•In September 2023, IDACORP's board of directors approved a 5.1 percent increase in the regular quarterly cash dividend on IDACORP’s common stock from $0.79 per share to $0.83 per share, as a part of a 177 percent increase in quarterly dividends approved over the last twelve years.

•In March 2023, Idaho Power executed an agreement with the ~~Bonneville Power Administration (BPA)~~BPA to transfer BPA's 24 percent interest in the Boardman-to-Hemingway 500-kV transmission line project to Idaho Power, bringing Idaho Power's 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 OPUC granted ~~certificates of public convenience and necessity (CPCN)~~CPCNs related to the 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.~~program for the procurement of renewable energy for customers.

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•In April 2023, the 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)~~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 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 additional 77 MW of company-owned storage it anticipates adding in 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)~~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~~At the time of the RFP issuance, Idaho Power’s long-range planning process ~~has~~had 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. RFP procurement decisions will be based on the most up-to-date energy and capacity need information. 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~~nine months ended ~~June~~September 30, 2023 and 2022 (in thousands, except earnings per share amounts):


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Idaho Power net income	Idaho Power net income	$	67,080	$	62,435	$	122,790	$	108,649	Idaho Power net income	$	103,022	$	104,532	$	225,812	$	213,181
Net income attributable to IDACORP, Inc.	Net income attributable to IDACORP, Inc.	$	68,574	$	64,287	$	124,672	$	110,548	Net income attributable to IDACORP, Inc.	$	105,264	$	106,380	$	229,936	$	216,928
Weighted average outstanding shares – diluted	Weighted average outstanding shares – diluted	50,758		50,687		50,741		50,673		Weighted average outstanding shares – diluted	50,805		50,722		50,762		50,689
IDACORP, Inc. earnings per diluted share	IDACORP, Inc. earnings per diluted share	$	1.35	$	1.27	$	2.46	$	2.18	IDACORP, Inc. earnings per diluted share	$	2.07	$	2.10	$	4.53	$	4.28

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


		Three months ended			Six months ended				Three months ended			Nine months ended
Net income attributable to IDACORP, Inc. - June 30, 2022			$	64.3		$	110.5
Net income attributable to IDACORP, Inc. - September 30, 2022								Net income attributable to IDACORP, Inc. - September 30, 2022		$	106.4		$	216.9
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	4.1			6.8			Customer growth, net of associated power supply costs and power cost adjustment mechanisms	4.6			11.4
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	(1.7)			(1.2)			Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms	(17.2)			(18.1)
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		2.4			10.8
Idaho FCA revenues								Idaho FCA revenues	7.2			6.2
Retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms								Retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms	0.9			11.0
Transmission wheeling-related revenues	Transmission wheeling-related revenues	1.7			6.8			Transmission wheeling-related revenues	(2.8)			4.0
Other operations and maintenance (O&M) expenses		3.4			3.5
Other O&M expenses								Other O&M expenses	4.9			8.3
Depreciation expense	Depreciation expense	(12.3)			(13.2)			Depreciation expense	(4.9)			(18.1)
Other changes in operating revenues and expenses, net	Other changes in operating revenues and expenses, net	3.0			(4.0)			Other changes in operating revenues and expenses, net	5.3			1.7

Increase in Idaho Power operating income		0.8			8.5
(Decrease) Increase in Idaho Power operating income								(Decrease) Increase in Idaho Power operating income	(2.0)			6.4
Non-operating expense, net	Non-operating expense, net	2.8			5.5			Non-operating expense, net	(0.5)			5.1
Additional accumulated deferred investment tax credits (ADITC) amortization		3.8			7.5
Additional ADITC amortization								Additional ADITC amortization	—			7.5
Income tax expense, excluding additional ADITC amortization	Income tax expense, excluding additional ADITC amortization	(2.8)			(7.4)			Income tax expense, excluding additional ADITC amortization	1.0			(6.4)
Total increase in Idaho Power net income			4.6			14.1
Total (decrease) increase in Idaho Power net income								Total (decrease) increase in Idaho Power net income		(1.5)			12.6
Other IDACORP changes (net of tax)	Other IDACORP changes (net of tax)		(0.3)			0.1		Other IDACORP changes (net of tax)		0.4			0.4
Net income attributable to IDACORP, Inc. - June 30, 2023			$	68.6		$	124.7
Net income attributable to IDACORP, Inc. - September 30, 2023								Net income attributable to IDACORP, Inc. - September 30, 2023		$	105.3		$	229.9

Net Income - ~~Second~~Third Quarter 2023

IDACORP's net income ~~increased $4.3~~decreased $1.1 million for the ~~second~~third quarter of 2023 compared with the ~~second~~third quarter of 2022, due primarily to lower net income at Idaho Power. At Idaho Power, customer growth increased operating income by $4.6 million in the third quarter of 2023 compared with the third quarter of 2022, as the number of Idaho Power customers grew by approximately 14,000, or 2.3 percent, during the twelve months ended September 30, 2023. Usage per customer decreased operating income by $17.2 million in the third quarter of 2023 compared with the third quarter of 2022. Greater precipitation and more moderate temperatures in Idaho Power's service area led agricultural irrigation customers to use less energy per customer to operate irrigation pumps and residential and commercial customers to use less energy per customer for cooling purposes in the third quarter of 2023 compared with the third quarter of 2022. The revenue impact of the decrease in sales volumes per customer was partially offset by the FCA mechanism (applicable to residential and small commercial customers), which increased revenues in the third quarter of 2023 by $7.2 million compared with the third quarter of 2022.

Transmission wheeling-related revenues decreased $2.8 million during the third quarter of 2023 compared with the third quarter of 2022, resulting primarily from lower wheeling volumes as energy prices in the western United States were less volatile, reducing transmission system demand and revenues.

Total other O&M expenses in the third quarter of 2023 were $4.9 million lower than in the third quarter of 2022, due primarily to lower maintenance expenses at hydropower facilities and jointly-owned coal plants as a result of fewer planned maintenance projects, as well as the timing of regulatory deferrals.

Depreciation expense increased $4.9 million in the third quarter of 2023 compared with the third quarter of 2022, due primarily to an increase in plant-in-service.

Other changes in operating revenues and expenses, net, increased operating income by $5.3 million in the third quarter of 2023 compared with the third quarter of 2022, due primarily to lower property taxes and 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 power purchase volumes and prices decreased Idaho Power's net power supply expenses in the third quarter of 2023 compared with the third quarter of 2022.

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Non-operating expense, net, increased $0.5 million in the third quarter of 2023 compared with the third quarter of 2022. Higher interest expense on long-term debt and other liabilities in the third quarter of 2023 compared with the third quarter of 2022 was mostly offset by an increase in AFUDC and higher interest income due to higher interest rates and higher average cash and cash equivalents balances.

Net Income - Year-To-Date 2023

IDACORP's net income increased $13.0 million for the first nine months of 2023 compared with the first nine months of 2022, due primarily to higher net income at Idaho Power. At Idaho Power, customer growth increased operating income by ~~$4.1~~$11.4 million infor the ~~second quarter~~first nine months of 2023 compared with the ~~second quarter~~first nine months of ~~2022, as the number of Idaho Power customers grew by approximately 13,100, or 2.1 percent, during the twelve months ended June 30, 2023.~~2022. Usage per customer decreased operating income by ~~$1.7~~$18.1 million induring the ~~second quarter~~first nine months of 2023 compared with the ~~second quarter~~first nine months of 2022, due primarily to ~~a 5 percent decrease in~~the lower usage per ~~industrial customer. In addition to slightly lower economic activity~~customer 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~~third quarter of 2023 described above. The revenue impact of the decrease in sales volumes per customer was partially offset by the FCA mechanism (applicable to residential and small commercial customers), which increased revenues in the first nine months of 2023 by $6.2 million compared with the ~~second quarter~~first nine months of ~~2022 when the co-generation facility was down for maintenance.~~2022.

The net increase in retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms, increased operating income by ~~$2.4~~$11.0 million in the ~~second quarter~~first nine months of 2023 compared with the ~~second quarter~~first nine months of 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 an order from the 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~~investments (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~~Transmission wheeling-related revenues increased $4.0 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 $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~~nine 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 six months of 2023 compared with the first six months of 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~~nine months of 2022, resulting from Idaho Power's ~~Open Access Transmission Tariff (OATT)~~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~~nine months of 2023 were ~~$3.5~~$8.3 million lower than the first ~~six~~nine 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 infrastructure 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~~$18.1 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~~was partially due to an increase in plant-in-service.

~~Other changes in operating revenues and expenses,~~Non-operating expense, net, decreased ~~operating income by $4.0~~$5.1 million in the first ~~six~~nine 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~~nine months of 2022. ~~Allowance for equity funds used during construction~~AFUDC increased as the average construction work in progress balance was higher throughout the first ~~six~~nine months of 2023 compared with the first ~~six~~nine months of 2022. Also, interest and investment income increased due to higher ~~market~~ interest ~~rates.~~rates and higher average cash and cash equivalents balances. These increases were partially offset by higher interest expense on long-term debt and other liabilities in the first ~~six~~nine months of 2023 compared with the first ~~six~~nine months of 2022.

Income tax expense in the first ~~six~~nine months of 2023 ~~was consistent~~decreased $1.1 million compared with the first ~~six~~nine months of 2022, as increased taxes from higher pre-tax income was more than offset by additional ADITC amortization. Based on Idaho Power's current expectations of full-year 2023 results, Idaho Power recorded $7.5 million of additional ADITC ~~amortization.~~amortization under its existing Idaho regulatory settlement stipulation during the first nine months of 2023. Idaho Power currently expects to amortize up to $10 million of additional ADITC for the full-year 2023, but 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~~September 30, 2023, Idaho Power's customer count grew by ~~2.1~~2.3 percent. While ~~inflationary and~~recessionary or volatile economic conditions could slow the rate of

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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~~filed its 2023 ~~Integrated Resource Plan (IRP),~~IRP, its 20-year forecast of power demand and supply ~~options.~~options, with the IPUC and OPUC in September 2023. 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~~under development by Meta Platforms, Inc. and ~~Micron.~~Micron Technology, Inc. (Micron). Included in the below table are Idaho Power's ~~preliminary~~ load forecast assumptions ~~the company anticipates using~~used 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			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)		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%
2023 IRP						2023 IRP	5.5%	3.7%	2.1%	1.8%
2021 IRP	2021 IRP	2.6%	2.1%	1.4%	1.4%	2021 IRP	2.6%	2.1%	1.4%	1.4%
2019 IRP	2019 IRP	1.3%	1.4%	1.0%	1.2%	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 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 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~~Idaho Power is undertaking a significant relicensing effort for the ~~Hells Canyon Complex (HCC),~~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.

As noted previously, Idaho Power believes that existing and sustained growth in customers, load, and peak demand for electricity, along with transmission constraints, has created the need for Idaho Power to acquire significant generation and storage resources to meet energy and capacity needs over the next several years. Idaho Power expects ~~to spend~~its capital expenditures on infrastructure investments in the next five years or more ~~than $600 million from 2023 through 2027 on resource additions~~will be considerable as it works to address projected energy and capacity 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; General Rate Case ~~Filing:~~Filing and Existing Settlement Stipulation: The prices that Idaho Power is authorized to charge for its electric and transmission service are 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 aan existing regulatory settlement stipulation in Idaho that includes provisions for the accelerated amortization of ADITC to help achieve a minimum 9.4 percent ~~Idaho-jurisdiction return on year-end equity (Idaho ROE).~~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 Idaho ROE, which would adjust to the authorized return on equity determined in ~~the next~~a general rate case. The settlement stipulation has no expiration date but the minimum Idaho ROE would revert back to 95 percent of the authorized return on equity determined in ~~the next~~an Idaho general rate case. The specific terms of the settlement

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stipulation, as currently in effect, are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2022 Annual Report.

On June 1, 2023, Idaho Power filed a general rate case ~~to adjust base customer~~application with the IPUC, requesting an average increase in net rates of 8.61 percent in Idaho, ~~on June~~effective January 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 ~~filing of~~need to file its Idaho general rate case including the increase in depreciation expense from ~~rate-base eligible~~rate base-eligible assets as they are placed into service, ~~(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, the expected financing costs for capital expenditures in a higher interest-rate environment, and, to a lesser extent, the inflationary pressures on other O&M expenses described above. On October 27, 2023, Idaho Power, the Staff of the IPUC, and intervening parties publicly filed the 2023 General Rate Case Settlement Stipulation with the IPUC related to the Idaho general rate case filing. The 2023 General Rate Case Settlement Stipulation is subject to approval by the IPUC. The general rate case filing and the 2023 General Rate Case Settlement Stipulation are described more fully in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report.

Idaho Power expects ~~the processing of its~~to make a general rate case filing in ~~Idaho will span at least seven months before new rates will be~~Oregon in ~~effect. In Oregon, Idaho Power expects~~December 2023 and that processing of a general rate case in Oregon would take approximately ten months.

•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, which lessen the potential earnings benefit or detriment of volatile hydrological conditions and their impact on overall power supply costs. For 2023, Idaho Power expects generation from its hydropower resources to be in the range of ~~6.0~~6.4 to ~~7.5~~6.8 million MWh, compared with 5.3 million MWh of hydropower generation in 2022 and a 30-year average annual total of 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 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, 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; 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. Moreover, environmental laws and regulations may increase the cost of constructing new facilities, may increase the cost of operating generation plants, may require that Idaho

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Power install additional pollution control devices at existing ~~generating~~generation 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 for the 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~~Valmy 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. 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 is described more fully in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. The preferred portfolio of Idaho Power’s 2023 IRP included the conversion of all coal generation units at the Valmy plant and Jim Bridger plant to natural gas generation units. Idaho Power would likely need to file an application with the IPUC to adjust the plant retirement dates for its gas-fired operations related to any potential conversions.

•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 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 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)~~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 actual incremental O&M expenses and depreciation expense of certain capital investments necessary to implement the WMP. The IPUC orders related to the WMP are described in more detail in the "Regulatory Matters" section of this MD&A. If approved by the IPUC, the 2023 General Rate Case Settlement Stipulation would allow continued deferral of incremental vegetation management and insurance costs, as measured from 2022 actual costs, through the earlier of Idaho Power’s next Idaho general rate case or 2025.

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~~nine months ended ~~June~~September 30, 2023. In this analysis, the results for the three months and ~~six~~nine months ended ~~June~~September 30, 2023, are compared with the same periods in 2022.

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


		Three months ended June 30,		Six months ended June 30,			Three months ended September 30,		Nine months ended September 30,
		2023	2022	2023	2022		2023	2022	2023	2022
Retail energy sales	Retail energy sales	3,694	3,648	7,385	7,273	Retail energy sales	4,654	4,897	12,039	12,170
Wholesale energy sales	Wholesale energy sales	330	121	538	149	Wholesale energy sales	171	182	697	320
Energy sales bundled with renewable energy credits	Energy sales bundled with renewable energy credits	429	179	782	550	Energy sales bundled with renewable energy credits	31	36	813	586
Total energy sales	Total energy sales	4,453	3,948	8,705	7,972	Total energy sales	4,856	5,115	13,549	13,076
Hydropower generation	Hydropower generation	2,430	1,602	3,805	2,866	Hydropower generation	1,559	1,354	5,363	4,219
Coal generation	Coal generation	180	777	608	1,595	Coal generation	844	1,288	1,452	2,883
Natural gas and other generation	Natural gas and other generation	307	179	1,187	638	Natural gas and other generation	1,035	844	2,222	1,482
Total system generation	Total system generation	2,917	2,558	5,600	5,099	Total system generation	3,438	3,486	9,037	8,584
Purchased power	Purchased power	1,856	1,723	3,756	3,504	Purchased power	1,798	1,874	5,541	5,378
Line losses	Line losses	(320)	(333)	(651)	(631)	Line losses	(380)	(245)	(1,029)	(886)
Total energy supply	Total energy supply	4,453	3,948	8,705	7,972	Total energy supply	4,856	5,115	13,549	13,076

Weather-related information for Boise, Idaho, for the three months and ~~six~~nine months ended ~~June~~September 30, 2023 and 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 September 30,			Nine months ended September 30,
		2023	2022	Normal (2)	2023	2022	Normal (2)		2023	2022	Normal (2)	2023	2022	Normal (2)
Heating degree-days(1)	Heating degree-days(1)	577	909	685	3,169	3,505	3,087	Heating degree-days(1)	49	13	94	3,218	3,518	3,181
Cooling degree-days(1)	Cooling degree-days(1)	246	157	188	246	157	188	Cooling degree-days(1)	1,076	1,233	847	1,322	1,390	1,035
Precipitation (inches)	Precipitation (inches)	3.0	4.6	3.4	6.7	7.3	7.2	Precipitation (inches)	2.1	0.3	0.8	8.8	7.6	8.0

(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 ~~increased 1~~decreased 5 percent and 21 percent in the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods in 2022, primarily due to weather variations that caused lower usage per customer. Greater precipitation and more moderate temperatures in Idaho Power's service area during the third quarter of 2023 led agricultural irrigation customers to use less energy per customer to operate irrigation pumps and residential and commercial customers to use less energy per customer for cooling purposes compared with same period in 2022. The decrease in usage per customer in both periods was partially offset by customer growth, inas the ~~number of Idaho Power customers. The~~ number of Idaho Power's customers grew by ~~2.1~~2.3 percent over the prior twelve ~~months, contributing to~~months. For more information on the ~~higher volumes.~~changes in sales volume, see the "Operating Revenues" section below in this MD&A.

~~Table~~Total system generation decreased 1 percent in the third quarter of ~~Contents~~

2023 compared with the third quarter of 2022, due primarily to lower retail sales described above. Total system generation increased ~~14 percent for the second quarter and 10~~5 percent in the first ~~six~~nine months of 2023 compared with the same ~~periods~~period in 2022, ~~comprised of an increase in hydropower generation and natural gas generation, partially offset by decreased coal generation.~~as total energy sales increased 4 percent. For more information on the changes in generation, see the "Operating Expenses" section below in 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 Cost Adjustment Mechanisms."

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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~~nine months ended ~~June~~September 30, 2023 and 2022, and the number of customers as of ~~June~~September 30, 2023 and 2022.


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Retail revenues:	Retail revenues:									Retail revenues:
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)		87,677		79,260		175,507		157,826
Residential (includes $5,583, $(1,447), $20,170, and $14,104, respectively, related to the FCA)(1)										Residential (includes $5,583, $(1,447), $20,170, and $14,104, respectively, related to the FCA)(1)	$	181,736	$	176,514	$	505,158	$	470,402
Commercial (includes $328, $142, $900, and $730, respectively, related to the FCA)(1)										Commercial (includes $328, $142, $900, and $730, respectively, related to the FCA)(1)	107,971		101,794		283,478		259,620
Industrial	Industrial	58,245		51,987		113,789		101,047		Industrial	67,522		60,306		181,312		161,353
Irrigation	Irrigation	62,781		57,659		63,713		58,700		Irrigation	104,645		105,365		168,358		164,065

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)	(2,815)		(2,815)		(6,861)		(6,861)

Total retail revenues	Total retail revenues	$	341,661	$	311,572	$	672,385	$	607,415	Total retail revenues	$	459,059	$	441,164	$	1,131,445	$	1,048,579
Volume of retail sales (MWh)	Volume of retail sales (MWh)									Volume of retail sales (MWh)
Residential	Residential	1,195		1,173		2,927		2,838		Residential	1,513		1,620		4,440		4,458
Commercial	Commercial	990		974		2,062		2,035		Commercial	1,150		1,192		3,212		3,227
Industrial	Industrial	858		852		1,735		1,737		Industrial	906		883		2,641		2,620
Irrigation	Irrigation	651		649		661		663		Irrigation	1,085		1,202		1,746		1,865
Total retail MWh sales	Total retail MWh sales	3,694		3,648		7,385		7,273		Total retail MWh sales	4,654		4,897		12,039		12,170
Number of retail customers at period end	Number of retail customers at period end									Number of retail customers at period end
Residential	Residential	524,191		512,594						Residential	528,298		515,790
Commercial	Commercial	77,817		76,573						Commercial	78,233		76,988
Industrial	Industrial	132		125						Industrial	132		127
Irrigation	Irrigation	22,309		22,063						Irrigation	22,330		22,092
Total customers	Total customers	624,449		611,355						Total customers	628,993		614,997

(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)~~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 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 increased ~~$30.1~~$17.9 million and ~~$65.0~~$82.9 million during the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods in 2022. The factors affecting retail revenues during the periods are discussed below.

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•Rates: Average customer rates, excluding amounts related to the power cost adjustment mechanisms, increased retail revenues by ~~$2.4~~$0.9 million and ~~$10.8~~$11.0 million, respectively, for the ~~first~~ three and ~~six~~nine months ended ~~June~~September 30, 2023, compared with the same periods in ~~2022,~~2022. The increase in the first nine months of 2023 was 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 revenues by ~~$22.7~~$31.2 million and ~~$44.4~~$75.4 million in the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods of 2022. 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.

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•Customers: Customer growth of ~~2.1~~2.3 percent during the twelve months ended ~~June~~September 30, 2023, increased retail revenues by ~~$6.7~~$7.5 million and ~~$12.0~~$19.6 million in the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods of 2022.

•Usage: Decreased usage (on a per customer basis)~~, primarily by industrial customers,~~ in all customer classes decreased retail revenues by ~~$1.9~~$28.9 million and ~~$1.2~~$29.3 million in the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods of 2022. ~~Usage per industrial customer decreased 5~~More precipitation in Idaho Power's service area during the spring and late summer of 2023 compared with the same period of 2022 led agricultural irrigation customers to use 10 percent and 36 percent inless energy per customer to operate irrigation pumps during the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods in 2022. Usage per residential and commercial customer during the third quarter and first nine months of ~~2022. In addition to slightly~~2023 was lower ~~economic activity in a few industrial sectors in both~~than the same periods in ~~2023, operation~~2022, primarily due to weather variations that caused these customers to use less energy per customer for cooling in the spring and early summer 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 the co-generation facility was down for maintenance.2023.

•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 commercial customers during the ~~second~~third quarter and first nine months of 2023 increased the amount of FCA revenue accrued by ~~$0.2~~$7.2 million and $6.2 million, respectively compared with the same period in 2022. Higher usage (on a per customer basis) by residential and small commercial customers during the first six months of 2023 decreased the amount of FCA revenue accrued by $1.0 million compared with the same periodperiods in 2022.

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Wholesale energy revenues	Wholesale energy revenues	$	15,201	$	6,980	$	45,397	$	10,015	Wholesale energy revenues	$	5,065	$	34,501	$	50,461	$	44,516
Wholesale MWh sold	Wholesale MWh sold	330		121		538		149		Wholesale MWh sold	171		182		697		320
Wholesale energy revenues per MWh	Wholesale energy revenues per MWh	$	46.06	$	57.69	$	84.38	$	67.21	Wholesale energy revenues per MWh	$	29.62	$	189.57	$	72.40	$	139.11

In the ~~second~~third quarter ~~and during the first six months~~ of 2023, wholesale energy revenues ~~increased $8.2~~decreased $29.4 million, ~~and $35.4 million, respectively,~~or 85 percent, compared with ~~the same periods~~third quarter of 2022, due primarily to ~~increases~~lower wholesale market prices. Wholesale energy revenues increased $5.9 million in the first nine months of 2023 compared with the first nine months of 2022, as higher wholesale energy sales volumes ~~sold. Wholesale MWh sold increased primarily due to higher hydro generation that resulted in more energy available for opportunistic~~were mostly offset by lower wholesale market ~~sales.~~prices. The increase in wholesale energy volumes sold during the ~~six~~nine months ended ~~June~~September 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 revenues by $16.7 million in the first ~~six~~nine months of 2023 and a corresponding amount was recorded in purchased power on the condensed consolidated statements of 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 this section of the MD&A under "Power Cost Adjustment Mechanisms."

Transmission Wheeling-Related Revenues: Transmission wheeling-related revenues ~~increased $1.7~~decreased $2.8 million, or 912 percent, and ~~$6.8~~increased $4.0 million, or 207 percent, during the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods of 2022. Milder weather in the southwest United States and Pacific Northwest during the third quarter of 2023 compared with the third quarter of 2022 led to a narrow price spread between energy market hubs which resulted in lower wheeling volumes. The increased wheeling revenue for the first nine months of 2023 compared with the same period of 2022 was primarily due to elevated energy prices in the western United ~~States.~~States during the first half of 2023 compared with the same period in 2022. Also, Idaho Power's OATT rates were approximately 1 percent higher in the first ~~half~~nine months of 2023 compared towith the first ~~half~~nine months of 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~~September 30, 2023, Idaho Power's energy efficiency rider balances were regulatory liabilities of ~~$1.2~~$2.6 million in the Idaho jurisdiction and ~~$0.6~~$0.8 million in the Oregon jurisdiction.

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Operating Expenses

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

Three months ended
June 30, Six months ended
June 30,
2023 2022 2023 2022
Expense
PURPA contracts $ 45,198 $ 48,607 $ 93,429 $ 88,603
Other purchased power (including wheeling) 46,262 43,120 169,125 88,548
Total purchased power expense $ 91,460 $ 91,727 $ 262,554 $ 177,151
MWh purchased
PURPA contracts 813 855 1,503 1,462
Other purchased power 1,043 868 2,253 2,042
Total MWh purchased 1,856 1,723 3,756 3,504
Average cost per MWh from PURPA contracts $ 55.59 $ 56.85 $ 62.16 $ 60.60
Average cost per MWh from other sources $ 44.35 $ 49.68 $ 75.07 $ 43.36
Weighted average - all sources $ 49.28 $ 53.24 $ 69.90 $ 50.56


	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Purchased power expense	$	142,851	$	192,884	$	405,404	$	370,035
MWh purchased	1,798		1,874		5,541		5,378
Average cost per MWh	$	79.45	$	102.93	$	73.16	$	68.81

Purchased power expense decreased ~~$0.3~~$50.0 million in the ~~second~~third quarter of 2023 compared with the ~~second~~third quarter of 2022, due primarily to ~~a decrease~~lower wholesale energy market prices as milder summer weather resulted in lower demand and lower fuel costs (natural gas and coal) in the ~~weighted average purchased power prices~~wholesale markets in the western United States compared with the ~~second~~third quarter of 2022. Purchased power expense increased ~~$85.4~~$35.4 million, or 4810 percent, in the first ~~six~~nine months of 2023 compared with the same period of 2022, due primarily to elevated wholesale energy prices in the western United States during the first half of 2023 and, to a lesser extent, higher generation from projects under ~~PURPA contracts and other purchased power.~~power purchase agreements.

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Expense	Expense									Expense
Coal	Coal	$	8,665	$	22,346	$	25,729	$	50,005	Coal	$	31,792	$	35,185	$	57,521	$	85,190
Natural gas	Natural gas	22,448		12,071		94,465		30,114		Natural gas	39,931		28,446		134,396		58,560
Total fuel expense	Total fuel expense	$	31,113	$	34,417	$	120,194	$	80,119	Total fuel expense	$	71,723	$	63,631	$	191,917	$	143,750
MWh generated	MWh generated									MWh generated
Coal	Coal	180		777		608		1,595		Coal	844		1,288		1,452		2,883
Natural gas	Natural gas	307		179		1,187		638		Natural gas	1,035		844		2,222		1,482
Total MWh generated	Total MWh generated	487		956		1,795		2,233		Total MWh generated	1,879		2,132		3,674		4,365
Average cost per MWh - Coal	Average cost per MWh - Coal	$	48.14	$	28.76	$	42.32	$	31.35	Average cost per MWh - Coal	$	37.67	$	27.32	$	39.62	$	29.55
Average cost per MWh - Natural gas	Average cost per MWh - Natural gas	$	73.12	$	67.44	$	79.58	$	47.20	Average cost per MWh - Natural gas	$	38.58	$	33.70	$	60.48	$	39.51
Weighted average, all sources	Weighted average, all sources	$	63.89	$	36.00	$	66.96	$	35.88	Weighted average, all sources	$	38.17	$	29.85	$	52.24	$	32.93

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~~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 ~~decreased $3.3~~increased $8.1 million, or 1013 percent, and $48.2 million, or 34 percent, in the ~~second~~third quarter and first nine months 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 2023respectively, compared with the same periods of 2022, despite lower total thermal generation. The ~~increase~~increases in fuel expense ~~in the first six months of 2023 compared with the same period of 2022, was~~were primarily due to higher natural gas market prices and higher coal purchase prices in ~~early~~ 2023, which resulted in an increase in the average cost per MWh of natural gas and coal generation. The mix of Idaho Power's thermal generation between natural gas and coal in the ~~second~~third quarter and first ~~half~~nine months 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 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-fired generation to meet customer demand during the second quarter and first half of 2023 compared with the same periods in 2022.periods.

Included in fuel expense are ~~losses~~gains and ~~gains~~losses on settled financial gas hedges entered into in accordance with Idaho Power's energy risk management policy. In the ~~second~~third quarter of 2023, losses on financial gas hedges of ~~$11.4~~$7.9 million increased natural gas fuel expense, while in the ~~second~~third quarter of 2022 and the first ~~six~~nine months of 2023 and 2022, gains on financial gas hedges of ~~$3.0~~

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$24.2 million, ~~$12.1~~$4.2 million, and ~~$4.5~~$28.6 million, respectively, reduced natural gas fuel expense. Most of these realized hedging ~~losses~~gains and ~~gains~~losses are passed on to customers through the 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)~~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. However, the IPUC directed Idaho Power to spread recovery of the March 31, 2023, PCA deferral balance over a two-year period from June 1, 2023, to May 31, 2025. Because of the power cost adjustment mechanisms, 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 customers in a future period, resulting in fluctuations in operating cash flows from year to year.

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


		Three months ended June 30,				Six months ended June 30,					Three months ended September 30,				Nine months ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Power supply cost accrual (deferral)		$	34,917	$	(1,026)	$	(25,351)	$	3,457
Power supply cost deferral										Power supply cost deferral	$	(22,131)	$	(42,885)	$	(47,482)	$	(40,246)
Oregon power supply cost accrual	Oregon power supply cost accrual	312		—		336		—		Oregon power supply cost accrual	—		—		335		—
Amortization of prior year authorized balances	Amortization of prior year authorized balances	14,400		600		23,307		(4,282)		Amortization of prior year authorized balances	28,030		12,079		51,338		8,615
Total power cost adjustment (income statement)	Total power cost adjustment (income statement)	$	49,629	$	(426)	$	(1,708)	$	(825)	Total power cost adjustment (income statement)	$	5,899	$	(30,806)	$	4,191	$	(31,631)

The power supply accruals (deferrals) represent the portion of the power supply cost fluctuations accrued (deferred) 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~~third 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~~and first ~~six~~nine 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: Total other O&M expenses decreased ~~$3.4~~$4.9 million, or 5 percent, and $8.3 million, or 3 percent, ~~and $3.5 million, or 2 percent,~~ in the ~~second~~third quarter and first ~~six~~nine months of 2023, respectively, compared with the same periods of 2022, due primarily to lower expenses from scheduled cyclical plant maintenance projects, ~~compared with~~as well as the ~~same period in 2022,~~timing of regulatory deferrals and payment credits received related to a jointly funded infrastructure project, offset partially by inflationary pressures on labor-related and other costs.

Income Taxes

IDACORP and Idaho Power income tax expense indecreased $0.8 million and $1.1 million, respectively, for the first ~~six~~nine months of 2023 ~~was consistent~~when compared with the ~~first six months~~same period of 2022, as increased taxes from higher pre-tax income was more than offset by $7.5 million of additional ADITC amortization. Idaho Power did not record any additional ADITC amortization in 2022. For information relating to IDACORP's and Idaho Power's computation of income tax expense, see Note 2 - "Income Taxes" to the condensed consolidated financial statements included in this report.

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LIQUIDITY AND CAPITAL RESOURCES

Overview

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 28,~~October 27, 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)~~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; ~~$630~~$280 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 credit facilities.

In 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:

•$60 million of 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.

InDuring 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 September 2023, Idaho Power issued $350 million of 5.80% first mortgage bonds, secured medium-term notes, Series M, maturing in April 2054. Idaho Power plans to use the proceeds for general corporate purposes including funding its capital projects.

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 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.

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 and thereafter for the foreseeable future 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, access to commercial paper, short-term and long-term debt 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~~September 30, 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	47%	48%	Debt	49%	50%
Equity	Equity	53%	52%	Equity	51%	50%

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IDACORP and Idaho Power 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~~believe they were in compliance with all credit facility and long-term debt ~~covenants.~~covenants at September 30, 2023. 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~~nine months ended ~~June~~September 30, 2023, were $7$162 million and $1$138 million, respectively, a decrease in cash flows from operations of ~~$149~~$107 million for IDACORP and ~~$144~~$156 million for Idaho Power, respectively, when compared with the same period in 2022. With the exception of cash flows related to income taxes, IDACORP's operating cash flows are principally derived from the operating cash flows from Idaho Power. Significant items that affected the companies' operating cash flows in the first ~~six~~nine months of 2023 when compared with the same period in 2022 were as follows:

•a ~~$14~~$13 million increase in IDACORP and Idaho Power net income;

•changes in ~~regulatory assets~~deferred taxes and ~~liabilities, mostly related~~taxes accrued and receivable combined to ~~the relative amounts of costs deferred~~increase IDACORP and ~~collected under the Bridger Order and wildfire mitigation cost deferral, decreased operating~~Idaho Power cash flows by ~~$17~~$32 million and $67 million, respectively;

•changes in contributions to pension and postretirement benefit plans decreased IDACORP and Idaho Power cash flows by $11 million; and

•changes in working capital balances due primarily to timing, including fluctuations as follows:

◦timing of accounts receivable and unbilled revenues increased operating cash flows by $47 million for IDACORP and $46 million for Idaho Power,

◦the changes in materials, supplies, and fuel stock decreased operating cash flows by ~~$31~~$49 million for IDACORP and Idaho Power, which was primarily due to an increase in material and supply inventory, ~~offset by~~and the timing of purchases and consumption of coal at Idaho Power's jointly-owned coal-fired generating plants; and

◦the changes in accounts and wages payable decreased operating cash flows by ~~$115~~$136 million for IDACORP and ~~$113~~$220 million for Idaho Power, which was primarily due to ~~an increase~~a decrease in power supply costs and associated timing of payments. The $84 million difference between IDACORP and Idaho Power is related to timing of intercompany estimated tax 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~~nine months ended ~~June~~September 30, 2023, were ~~$264~~$412 million and ~~$263~~$403 million, respectively. Investing cash outflows for 2023 ~~and 2022~~ were primarily for construction of utility infrastructure needed to address Idaho Power’s customer growth, aging plant and equipment, ~~customer growth,~~ and environmental and regulatory compliance requirements. Significant items and transactions that affected investing cash flows in the first ~~six~~nine months of 2023 ~~were as follows:~~included:

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•~~IDACORP’s and Idaho Power’s investing cash outflows for 2023 included $274~~$427 million of additions to property, plant and equipment, including ~~$47~~$92 million spent on battery storage projects, and at ~~June~~September 30, 2023, ~~$49~~$8 million was accrued in accounts payable on their consolidated balances sheets related to battery storage projects;

•~~IDACORP’s and Idaho Power's investing cash inflows for 2023 included $9~~$15 million received 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 $5 million investment in IERCo, a wholly-owned subsidiary of Idaho Power;~~ and

•~~IDACORP’s and Idaho Power's investing cash inflows for 2023 included $4~~$6 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.~~SMSP.

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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~~nine months ended ~~June~~September 30, 2023, were ~~$214~~$518 million and ~~$257~~$561 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. Significant items and transactions that affected financing cash flows in the first ~~six~~nine months of 2023 were as follows:

•in March 2023, Idaho Power repaid $100 million in principal amount of a March 2022 term loan 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;

•in September 2023, Idaho Power issued $350 million in principal amount of 5.80% first mortgage bonds, secured medium-term notes, Series M, maturing in April 2054; and

•IDACORP and Idaho Power paid dividends of ~~$81~~$121 million and ~~$41~~$81 million in 2023, respectively.

Available Short-Term Borrowing Liquidity

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


		June 30, 2023				December 31, 2022					September 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)	—		(19,885)		—		(19,885)		Identified for other use(1)	—		(19,885)		—		(19,885)
Net balance available	Net balance available	$	100,000	$	280,115	$	100,000	$	280,115	Net balance available	$	100,000	$	280,115	$	100,000	$	280,115

(1) 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.

49Idaho Power has regulatory authority through December 2026 to incur up to $450 million in principal amount of short-term borrowing indebtedness at any one time outstanding. Idaho Power submitted applications to the IPUC, OPUC, and WPSC in October 2023, requesting authorization for the company to incur, issue, and sell from time to time up to $600 million in aggregate principal amount at any one time of unsecured borrowings through December 2030.

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On ~~July 28,~~October 27, 2023, IDACORP and Idaho Power had no loans outstanding under their revolving credit facilities and had no commercial paper outstanding.

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The table below presents additional information about short-term commercial paper borrowing (in thousands) during the three and ~~six~~nine months ended ~~June~~September 30, 2023.


	Three months ended ~~June~~September 30, 2023						~~Six~~Nine months ended ~~June~~September 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~~12,301
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 ~~Standard & Poor’s~~S&P Global Ratings ~~Services~~ or Moody’s Investors Service from those included in the 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.

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~~September 30, 2023, Idaho Power had posted ~~$44~~$29 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 then-existing market conditions, as of ~~June~~September 30, 2023, the amount of additional collateral that could behave been requested upon a downgrade to below investment grade iswas approximately ~~$19~~$10 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 cash capital expenditures, excluding AFUDC, were ~~$265~~$413 million during the ~~six~~nine months ended ~~June~~September 30, 2023. The table below presents Idaho Power's estimated accrual-basis additions to property, plant, and equipment for 2023 (including amounts incurred to-date) through 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. Given the uncertainty associated with the timing of infrastructure projects and associated expenditures, actual expenditures and their timing 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,~~RFPs and ~~preliminary~~ 2023 IRP ~~modeling~~ in order to safely and reliably serve ~~the company's~~Idaho Power'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 reasonable costs, supply chain disruptions and delays, regulatory determinations, inflationary pressures, macroeconomic conditions, or other issues, including those described below.

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


	2023	2024	2025-2027
Expected capital expenditures (excluding AFUDC)	$675-$725	$850-$950	$2,000-$2,500

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 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's existing and sustained growth in customers, load, and peak demand for electricity, along with transmission constraints, 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. To help meet peak needs in 2023 through 2025, Idaho Power entered ~~into or expects to enter~~ into contracts to purchase, own, and operate 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 three power purchase agreements for the combined 340 MW output of planned third-party solar facilities with 20- to 25-year terms. As described in “Regulatory Matters” of this MD&A, Idaho Power plans to sell the output of two of these solar power purchase agreements totaling 240 MW exclusively to two large industrial customers under agreements modeled after Idaho Power’s ~~proposed~~ Clean Energy Your Way program. To help address the additional capacity deficits projected for 2026 through 2027, Idaho Power has issued an RFP for additional resources. The capital requirements table above includes capital expenditures of more than ~~$600~~$400 million ~~from~~in the years 2023 through ~~2027~~2025 for resource additions to address projected energy and capacity deficits in those ~~years.~~years, but does not currently include any amounts for possible company-owned resources from the RFP to address projected deficits in 2026 or 2027. Depending on factors such as RFP results, the timing of project in-service dates, 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's expected expenditures.

Boardman-to-Hemingway Transmission Line: The Boardman-to-Hemingway line, a planned 300-mile, high-voltage transmission project between a substation near Boardman, Oregon, and the Hemingway substation near Boise, Idaho, is expected to provide transmission service to meet future resource needs. Material procurement and construction subcontract bid events are in ~~progress~~progress. As a result of delays in issuing Notices to Proceed from state and federal agencies, Idaho Power expects construction towill begin in the ~~second~~first half of ~~2023.~~2024. 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 BPA to pursue permitting of the project, with Idaho 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 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 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.

Idaho Power has spent approximately $198~~$169~~ million, including Idaho Power's AFUDC, on the Boardman-to-Hemingway project through ~~June~~September 30, 2023. Pursuant to the terms of the joint funding arrangements, Idaho Power has received ~~$107~~$113 million in reimbursement as of ~~June~~September 30, 2023, from project co-participants for their share of 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~~ and continues to receive reimbursement as costs are ~~outstanding.~~incurred. The remaining joint permitting participant is obligated to reimburse Idaho Power for 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 was subject to federal review and approval by various federal agencies. Federal agency records of decision have been received and all lawsuits challenging the 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 final order and site certificate. Three parties filed appeals to the Oregon Supreme Court asking that court to overturn EFSC's approval of the 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 became fully effective in September 2023 upon the ~~agreement will go into effect upon~~ meeting of the conditions precedent contained in the agreement ~~relating to~~including acceptance of the agreement by the FERC, receipt of the CPCNs for Boardman-to-Hemingway from Oregon and

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Idaho for Idaho Power and Idaho and Wyoming for PacifiCorp, and Idaho Power and PacifiCorp consenting to the conditions contained within their respective CPCNs.

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AsDuring the second quarter of ~~June~~ 2023, the IPUC, OPUC, and Wyoming Public Service Commission ~~have~~ granted ~~or made oral decisions approving,~~ Idaho Power and PacifiCorp their respective CPCNs related to the construction of the Boardman-to-Hemingway project.

Total cost estimates for the project are ~~trending toward the upper end of Idaho Power's estimated cost range of~~ between ~~$1.1~~$1.5 billion and ~~$1.3~~$1.7 billion, including Idaho Power's AFUDC. The capital requirements table above includes approximately ~~$430~~$640 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~~Actual construction costs could ~~change as the construction timeline nears~~differ from Idaho Power's estimates based upon Idaho Power’s or its contractors ability to timely obtain labor or materials at reasonable costs, supply chain disruptions and ~~as the project participants obtain more detailed information on construction and material costs.~~delays, inflationary pressures, macroeconomic conditions, or other issues.

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 2012, Idaho Power and PacifiCorp entered a joint funding agreement for permitting of the project. Idaho Power has expended approximately ~~$57~~$58 million, including Idaho Power's AFUDC, for its share of the permitting phase of the project through ~~June~~September 30, 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 $300 million and $500 million, including AFUDC. The capital requirements table above includes approximately $40 million of Idaho Power's share of estimated costs (excluding AFUDC) for the permitting phase of the project and early construction costs, based on Idaho Power's current estimate that it may commence construction of applicable segments during that time period.

The permitting phase of the Gateway West project was subject to review and approval of the 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 completed construction and commissioned a 140-mile segment of 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,~~Boise, Idaho. Idaho Power and PacifiCorp continue to coordinate the timing of next steps to best meet customer and system ~~needs.~~needs including potentially modifying the ownership structure of a few segments of the project.

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 in the range of between $900 million and $1.1 billion, including Idaho Power's AFUDC. The estimated cost range includes the possibility of an increase in Idaho Power participation in the construction of certain project segments, for which Idaho Power would need to coordinate with PacifiCorp. The capital requirements table above includes approximately $370 million of Idaho Power's share of estimated costs (excluding AFUDC) for the permitting phase of the project and early construction costs, based on Idaho Power's current estimate that it may commence construction of applicable segments during that time period. Actual construction costs could differ from Idaho Power's estimates based upon the ability of Idaho Power, PacificCorp, or their respective contractors to timely obtain labor or materials at reasonable costs, supply chain disruptions and delays, inflationary pressures, macroeconomic conditions, or other issues.

Defined Benefit Pension Plan Contributions

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in 2023, and during the ~~six~~nine months ended ~~June~~September 30, 2023, Idaho Power made ~~a $10~~contributions of $48 million ~~contribution. Idaho Power is considering contributing up to an additional $30 million to its pension plan during 2023~~ in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions, as well as to mitigate the cost of being in an underfunded position. 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 have not materially changed during the ~~six~~nine months ended ~~June~~September 30, 2023, except as disclosed in Note 5 – “Long-Term Debt” and Note 8 – “Commitments” to the condensed consolidated financial statements included in this 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

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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 IDACORP and Idaho Power dividends, including restrictions on IDACORP’s and Idaho Power’s payment of dividends, see Note 6 - “Common Stock” to the 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 2022 Annual Report.

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 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. In recognition of Idaho Power’s current and anticipated significant infrastructure investments, including those that are intended to help meet projected near-term capacity deficits, Idaho Power filed a general rate case in Idaho on June 1, 2023. As discussed below, the 2023 General Rate Case Settlement Stipulation was filed for that rate case on October 27, 2023. Idaho Power's most recent previous general rate cases in Idaho and Oregon were filed ~~during~~in 2011, and induring 2012, large single-issue rate cases for the Langley Gulch power plant ~~resulted in the resetting of~~reset 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. Idaho Power expects to file a general rate case in Oregon in December 2023.

Between general rate cases, Idaho Power relies upon customer growth, aan 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 filed a general rate case in Idaho on June 1, 2023, with a general rate 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 2022 Annual Report. In addition to the discussion below, which includes notable regulatory developments since the discussion of these matters in the 2022 Annual Report, refer to Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report for additional information ~~relating to~~regarding Idaho Power's Idaho general rate case filing and other regulatory matters and recent regulatory filings and orders.

Idaho General Rate Case and Filing of 2023 General Rate Case Settlement Stipulation

On June 1, 2023, Idaho Power filed a general rate case and proposed rate schedules for the Idaho jurisdiction with the IPUC. On October 27, 2023, Idaho Power, the Staff of the IPUC, and intervening parties publicly filed the 2023 General Rate Case Settlement Stipulation related to the Idaho general rate case filing. If the IPUC approves the 2023 General Rate Case Settlement Stipulation, it will authorize Idaho Power's filed general rate case, with the modifications contained in the 2023 General Rate Case Settlement Stipulation.

The 2023 General Rate Case Settlement Stipulation provides that Idaho Power would implement revised tariff schedules designed to recover $54.7 million in additional annual revenue from Idaho jurisdictional base rates effective January 1, 2024, representing a 4.25 percent overall average increase in Idaho Power's annual Idaho jurisdictional base rate revenues. The $54.7 million of additional annual revenue is net of a PCA rate decrease of $168.3 million (moving that amount from collection via the PCA and into base rates) and a reduction to annual energy efficiency rider collection of $3.5 million. The 2023 General Rate

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Case Settlement Stipulation also provides for a 9.6 percent return on equity and a 7.247 percent authorized rate of return based on a non-specified cost of debt and capital structure, applied to an Idaho-jurisdictional rate base of approximately $3.8 billion. Idaho Power had requested a 10.4 percent authorized rate of return on equity and an approximate $3.9 billion Idaho retail rate base. See Note 3 – "Regulatory Matters" to the condensed consolidated financial statements included in this report for a more detailed summary of the significant provisions of the general rate case filing and proposed 2023 General Rate Case Settlement Stipulation.

The parties to the 2023 General Rate Case Settlement Stipulation agreed that certain matters would be examined in either separate, subsequent proceedings or continued in the general rate case docket. Those additional matters relate to, among other items, further review of Idaho Power plant investments by IPUC Staff to be completed by December 1, 2023, class cost-of-service methodology, and rate design related to time-of-use rates. The 2023 General Rate Case Settlement Stipulation provides that these subsequent proceedings will not impact the agreements reached in the 2023 General Rate Case Settlement Stipulation. To the extent Staff identifies potential prudence concerns, those prudence concerns would be addressed in Idaho Power's next general rate case.

The parties to the 2023 General Rate Case Settlement Stipulation have requested that the IPUC issue an order approving the agreed-upon rates effective January 1, 2024. Idaho Power is unable to predict whether the IPUC will approve the 2023 General Rate Case Settlement Stipulation or the ultimate outcome of the general rate case proceedings.

The 2023 General Rate Case Settlement Stipulation does not preclude Idaho Power from filing another general rate case in Idaho at any time in the future.

Notable Retail Rate Changes

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

Description

Status

Estimated Rate Impact(1)

Notes

~~Power Cost Adjustment~~PCA Mechanism - Idaho

New PCA rate became effective June 1, 2023

$105.1 million PCA increase for the period from June 1, 2023, to May 31, 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 higher costs associated with market energy and natural gas prices, combined with limited coal supply. The IPUC order approving the PCA increase defers collection of $95.1 million of deferred PCA costs to the subsequent annual PCA collection period.

~~Fixed Cost Adjustment~~FCA Mechanism - Idaho

New FCA rate became effective June 1, 2023

$10.1 million FCA decrease for the period from June 1, 2023, to
May 31, 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)~~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~~ADITC and Revenue Sharing ~~from Idaho Settlement Stipulation~~Mechanism

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 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 2023 Idaho ROE, in the three and ~~six~~nine months ended ~~June~~September 30, 2023, Idaho Power recorded ~~$3.8 million~~zero and $7.5 million, respectively, in additional ADITC amortization under the May 2018 Idaho Tax Reform Settlement Stipulation. Accordingly, at ~~June~~September 30, 2023, $37.5 million of additional ADITC remains available for future use. Idaho Power recorded no additional ADITC amortization or provision against revenues for sharing of earnings with customers during 2022. If approved by the IPUC, the 2023 General Rate Case Settlement Stipulation would modify the Idaho ADITC and revenue sharing mechanism as described in Note 3 – "Regulatory Matters" to the condensed consolidated financial

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statements included in this report.

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~~nine months ended ~~June~~September 30, 2023 (in millions).


		Idaho		Oregon		Total			Idaho		Oregon		Total
Deferred net power supply costs at December 31, 2022	Deferred net power supply costs at December 31, 2022	$	128.7	$	0.6	$	129.3	Deferred net power supply costs at December 31, 2022	$	128.7	$	0.6	$	129.3
Current period net power supply costs deferred (accrued)	Current period net power supply costs deferred (accrued)	25.3		(0.3)		25.0		Current period net power supply costs deferred (accrued)	47.5		(0.3)		47.2

Prior amounts collected through rates	Prior amounts collected through rates	(23.3)		—		(23.3)		Prior amounts collected through rates	(51.3)		(0.1)		(51.4)
SO2 allowance and renewable energy certificate net sales	SO2 allowance and renewable energy certificate net sales	(7.6)		(0.3)		(7.9)		SO2 allowance and renewable energy certificate net sales	(9.5)		(0.4)		(9.9)
Interest and other	Interest and other	2.9		—		2.9		Interest and other	4.4		—		4.4
Deferred net power supply costs at June 30, 2023		$	126.0	$	—	$	126.0
Deferred (accrued) net power supply costs at September 30, 2023								Deferred (accrued) net power supply costs at September 30, 2023	$	119.8	$	(0.2)	$	119.6

2023 Integrated Resource Plan

Idaho Power filed its most recent IRP with the IPUC and OPUC in September 2023. The 2023 IRP assumes a forecasted annual growth in average energy demand of 2.1 percent and a forecasted annual growth in peak-hour demand of 1.8 percent over the 20-year period. The 2023 IRP preferred resource portfolio and action plan adds 6,888 MW of resource capacity over the next 20 years to meet energy and capacity needs, including the addition of 3,325 MW of solar, 1,800 MW of wind, 1,453 MW of storage, 360 MW of additional energy efficiency, 340 MW of hydrogen, 160 MW from demand response, and 30 MW of geothermal. In addition, the preferred resource portfolio includes Idaho Power's complete exit from coal-fired generation by 2030 and the conversions of multiple jointly-owned coal-fired generation units to natural gas, adding a net total of 261 MW of generation capacity through 2043. To support these resource additions, the preferred portfolio also includes the Boardman-to-Hemingway transmission line in 2026 and three Gateway West transmission line segments phased in with in-service dates from 2028 through 2040. However, as noted in the 2023 IRP, there is considerable uncertainty surrounding the resource sufficiency estimates and project completion dates, including uncertainty around the timing and extent of third party development of renewable resources, fuel commodity prices, and the actual completion date of the transmission projects. These uncertainties, as well as others, could result in changes to the desirability of the preferred portfolio and adjustments to the timing and nature of anticipated and actual actions.

Open Access Transmission Tariff ~~Draft~~ Posting

Idaho Power uses a formula rate for transmission service provided under its OATT, which provides that transmission rates will be updated annually based primarily on financial and operational data Idaho Power files with the FERC. ~~The existing OATT rate in effect from~~In October ~~1, 2022, to September 30, 2023, is $31.42 per "kW-year" based on a net annual transmission revenue requirement of $132.7 million.~~ ~~In May~~ 2023, Idaho Power ~~publicly posted~~filed its 2023 ~~draft~~final transmission rate with the FERC, reflecting a transmission rate of ~~$31.13~~$30.74 per "kW-year," to be effective for the period from October 1, 2023, to September 30, 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~~final rate was based on aan annual net ~~annual~~point-to-point transmission revenue requirement of ~~$137.4~~$135.7 million. The OATT rate in effect from October 1, 2022, to September 30, 2023, was $31.42 per kW-year based on an annual net point-to-point transmission revenue requirement of $132.7 million.

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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 Boardman-to-Hemingway project is described in more detail in the "Liquidity and Capital Resources" section of this MD&A.

Oregon Resource Procurement Filing

The State of Oregon has competitive bidding rules regarding a public utility's procurement of resources. However, as allowed by the ~~OPUC~~rules in certain cases, Idaho Power is pursuing ~~an exception~~exceptions for ~~2023 resource needs, and plans to pursue additional exceptions to the competitive bidding rules for certain projects to meet the~~its identified ~~resource needs in~~2023, 2024, and ~~2025.~~2025 resource needs.

In July 2023, following review by an independent evaluator appointed by the OPUC, OPUC staff, and other ~~intervenors,~~intervening parties, the OPUC issued an order approving issuance of Idaho Power's final RFP to procure resources for its anticipated energy and capacity needs in 2026 and 2027.

Jim Bridger Power Plant Base Rate Adjustment and Recovery

In June 2022, the IPUC issued the Bridger Order approving, with modifications, Idaho Power’s amended application requesting authorization to (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, (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 (3) increase customer rates related to the associated incremental annual levelized revenue requirement. The Bridger Order and associated accounting are described in Note 3 – “Regulatory Matters” to the condensed consolidated financial statements included in this report. Idaho Power plans to cease participation in all coal-related operations at the Jim Bridger plant by 2028.

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 projected spending approximately $47 million in incremental wildfire mitigation-related O&M and roughly $35 million in wildfire mitigation system-hardening incremental capital expenditures over a ~~five year~~five-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~~September 30, 2023, Idaho Power’s deferral of Idaho-jurisdiction costs related to the WMP was ~~$39.5~~$45.4 million.

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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 October 2022, Idaho Power filed an 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 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 a new large load customer, Brisbie, LLC (Brisbie), a wholly-owned subsidiary of Meta Platforms, Inc., would purchase from Idaho Power 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 200-MW solar facility pursuant to a long-term power purchase agreement between Idaho Power and a third party. The solar facility is scheduled to begin operating as early as 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 expects to procure enough renewable resources to ~~provide Brisbie with~~support 100 percent ~~renewable energy~~of Brisbie's operations on an annual basis ~~for Brisbie’s facility.~~with new renewable resources. The ~~IPUC approval of the~~modified special contract ~~requires Idaho Power to file a modified energy services agreement~~ and related rate schedule ~~which Idaho Power plans to file~~were approved by ~~August 9,~~the IPUC in October 2023.

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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 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.

Lamb Weston, Inc. Special Contract: In ~~May~~September 2023, the IPUC issued an order approving Idaho ~~Power filed an application for approval of a~~Power's special contract for electric service for an existing large load customer, Lamb Weston, Inc. (Lamb Weston). Idaho Power 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~~in the ~~date of this report, the IPUC's decision in this matter is pending.~~near future.

~~Western Resource Adequacy~~Clean Energy Your Way Program

: In ~~March~~August 2023, the IPUC approved Idaho Power's application to expand optional customer clean energy offerings through its new Clean Energy Your Way Program. Specifically, Idaho Power ~~filed an application with~~received authority to: (1) rename its existing green power program; (2) maintain and expand procurement options for the ~~IPUC requesting that the IPUC issue an order acknowledging the potential~~renewable energy credits; (3) establish a regulatory framework for ~~long-term cost savings associated with~~a future voluntary subscription green power service program; (4) offer a tailored renewable option for Idaho Power's ~~participation in~~largest customers; and (5) procure the Western Resource Adequacy Program (WRAP), and allowing the company to recover WRAP-associated costs in a future rate proceeding. The WRAP is a regional reliability and compliance program being developed in western North America with the intent of providing a region-wide approach for assessing and addressing resource adequacy and reliability. Idaho Power 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 extreme need. Asassociated additional resources outside of the ~~date of this report, the~~ IPUC's ~~determination in this matter is pending~~.current competitive procurement requirements.

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 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

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to the grid and Idaho Power 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 IPUC issued an order establishing a 25-year grandfathering term for large commercial, industrial, and irrigation customers, similar to the terms approved for the residential and small commercial customer classes.

In June 2022, as directed by the IPUC, Idaho Power filed a comprehensive study on the costs and benefits of on-site generation based on the IPUC’s study framework findings and conclusions, and in December 2022, the IPUC issued an order that acknowledged ~~the company's~~Idaho Power's study and directed Idaho Power to file a new case requesting to implement changes to the structure and design of its on-site generation program. In May 2023, Idaho Power filed a new case as directed by the IPUC, requesting the IPUC to implement changes for non-grandfathered customers starting January 1, 2024, including: 1)(1) a change from net monthly to real-time net billing, which would better measure customers’ actual reliance on the grid; 2)(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)(3) a modification to the eligibility cap for large commercial, industrial, and irrigation customers. As of the date of this report, the IPUC's determination in this matter is 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~~September 30, 2023, Idaho Power had contracts to purchase energy from 129 online PURPA projects. An additional 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.

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The following table sets forth, as of ~~June~~September 30, 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	Online (MW)	Under Contract but not yet Online (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	625	—	625	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	43	—	43
Total	Total	1,135	75	1,210	Total	1,134	75	1,209
Non-PURPA:	Non-PURPA:				Non-PURPA:
Wind	Wind	101	—	101	Wind	101	—	101
Geothermal	Geothermal	35	—	35	Geothermal	35	—	35
Solar	Solar	160	300	460	Solar	160	300	460
Total	Total	296	300	596	Total	296	300	596

The PURPA-qualifying facility projects not yet online include one hydropower project that is scheduled to be online in 2023, and ~~three~~one PURPA-qualifying facility solar ~~projects~~project expected to be online in 2024. The table above also includes two PURPA-qualifying facility solar projects not yet online, totaling 71 MW, for which Idaho Power expects to terminate the existing agreements by January 31, 2024, due to non-performance by the contractual counterparties. Two non-PURPA solar projects, for 100 MW and 200 MW, are scheduled to be online in 2024 and 2025, ~~respectively~~.respectively. In ~~February~~August 2023, ~~Idaho Power filed an application with~~ the IPUC ~~requesting~~issued an order approving ~~the~~ Idaho Power's 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 2024. ~~As of the date of this report, the IPUC's determination in this matter is pending.~~

In April 2023, Idaho Power entered into an agreement, pending regulatory approval, with a 150-MW battery storage facility, scheduled to be online in June 2025. Under the agreement, the facility would provide 150 MW of capacity on Idaho Power’s system for a period of 20 years, and Idaho Power would have the exclusive right to dispatch and use the charging and discharging energy in exchange for a monthly payment. In May 2023, Idaho Power filed an application with the 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 that the IPUC issue an order granting Idaho Power a ~~certificate of public convenience and necessity~~CPCN to acquire a total of 101 MW of new dispatchable energy storage to meet identified capacity deficiencies in both 2024 and 2025. As of the 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, as described in more detail in the 2022 Annual Report in Part II, Item 7 - "Regulatory Matters," Idaho Power submitted to the FERC in July 2020 its supplement to the final license application. The supplement incorporated the settlement agreement reached between Idaho and Oregon on the ~~Clean Water Act (CWA)~~CWA Section 401 certifications, which precipitated the states issuing final CWA Section 401 certifications in May 2019. The states of Idaho and Oregon also submitted the CWA Section 401 certifications to the FERC as part of the relicensing process. The supplement included feedback on proposed modifications of the 2007 final ~~environmental impact statement (EIS)~~EIS for the HCC, as well as an updated cost analysis of the HCC and a request that the FERC 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)~~USFWS and the ~~National Marine Fisheries Service (NMFS)~~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).~~ESA. Since December 2020, Idaho Power has responded to sixteen additional information requests issued by the FERC staff to aid in the FERC's analysis.

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In June 2022, the FERC issued a Notice of Intent ~~(NOI)~~ to prepare a supplemental EIS in accordance with NEPA. The FERC indicated that the supplemental EIS would address the new and revised measures proposed by the CWA 401 certification settlement, the conditions contained in the Oregon and Idaho water quality certifications, and the information provided in the draft biological assessments. The FERC also reinitiated informal consultation with the USFWS and the NMFS under section 7 of the ESA. In ~~the notice of intent,~~October 2023, the FERC ~~predicted that~~issued a notice revising the schedule for completing the supplemental EIS. Under the revised schedule, the draft supplemental EIS ~~would~~is targeted to be published in ~~June 2023~~February 2024 and the final supplemental EIS in ~~December 2023; an updated NOI has not yet been issued.~~November 2024.

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 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~~2025 or thereafter.

Relicensing costs for Idaho Power's hydropower projects are recorded as 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 ~~$441~~$450 million (including AFUDC) for the HCC were included in construction work in progress at ~~June~~September 30, 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~~September 30, 2023, Idaho Power's regulatory liability for collection of AFUDC relating to the HCC was approximately ~~$218~~$224 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. In February 2023, following the public comment period on its draft

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license application, Idaho Power filed a final license application with the FERC. In July 2023, FERC issued a notice that Idaho Power’s final license application was accepted for filing and solicited motions to intervene and protest. In September 2023, FERC issued a request for comments to determine the resource issues that should be addressed in the environmental analysis and identify reasonable alternatives to the proposed action that FERC should evaluate under the NEPA framework. 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.

In September 2023, Idaho Power filed an application for CWA Section 401 water quality certification with the IDEQ. The IDEQ acknowledged receipt of the Section 401 water quality certification application and informed Idaho Power that it anticipates preparing a draft certification and will seek public comment once the draft is complete. American Falls' current license expires in 2025, 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 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 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 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 a number of water discharge standards and other environmental requirements.

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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 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 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 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 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 cannot be fully recovered in rates on a timely basis.

Part I - "Business - Utility Operations - Environmental Regulation and Costs" in the 2022 Annual Report, includes a summary of Idaho Power's expected capital and operating expenditures for environmental matters during the period from 2023 to 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 beyond 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 2022 Annual Report. 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 May 2023, the USFWS published a revised Mitigation Policy and a revised ESA Compensatory Mitigation Policy (Revised Policies) which together establish fundamental mitigation principles and compensatory mitigation standards and application guidance through implementation of the ESA. The Revised Policies scale back the mitigation goal from the previous policies by including a nexus and proportionality principle to reinforce that government-required mitigation measures must have a clear connection with the anticipated ~~effects~~effects of the proposed land use. As of the date of this report, Idaho Power is uncertain to what extent the Revised Policies may impact its obligations in permitting infrastructure, including relicensing its ~~hydroelectric~~hydropower facilities, and transmission lines.

Clean Air Act Matters

Good Neighbor Plan: In June 2023, the ~~U.S. Environmental Protection Agency (EPA)~~EPA published the final rule under the CAA called the Federal "Good Neighbor Plan" for the 2015 Ozone National Ambient Air Quality Standards (Good Neighbor Plan), ~~to be effective~~which took effect on 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. The EPA's final rule temporarily excludes power plants located in Wyoming, while the EPA reevaluates the proposed disapproval of the Wyoming state implementation plan (SIP). In August 2023, the EPA published a proposed approval of the Wyoming SIP, finding that the EPA’s updated modeling demonstrated that Wyoming’s determination that no additional controls are required to address interstate transport for the 2015 zone National Ambient Air Quality Standards was reasonable. In September 2023, Idaho Power submitted comments in support of EPA’s proposed approval of the Wyoming SIP. Refer to Part II, Item 7 - "MD&A - Environmental Issues" in the 2022 Annual Report for more information on SIPs.

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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. In light of the court's ruling, in September 2023, the EPA issued an interim final rule indefinitely suspending the implementation of the Good Neighbor Plan in Nevada. As of the date of this report, Idaho Power continues to evaluate the specific impacts the Good Neighbor Plan could have on its operations at the Valmy and Jim Bridger plants. If the Good Neighbor Plan is implemented in Nevada and Wyoming, Idaho Power anticipates that, under certain conditions, it could reduce the ability to use the full available output, or require the purchase of allowances in order to utilize 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~~greenhouse gas (GHG) emissions reductions on new and existing natural gas-fired generating units and coal plants expected to be operational in 2040 and beyond. The proposed rule would require states to submit plans to the EPA to implement standards for existing sources within 24 months of the effective date of the emission guidelines. In August 2023, Idaho Power submitted comments to the EPA requesting it to maintain certain jurisdictional limits published in the rule and create flexibility for state plans to account for system reliability. As of the date of this report, Idaho Power continues to evaluate the specific impacts the proposed rule could have on its operations at its three natural gas facilities, as well as the Valmy and Jim Bridger plants. If the proposed rule is implemented, Idaho Power anticipates that the 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: ~~Since 2015, the EPA and U.S. Army Corps of Engineers have been attempting to define the scope~~The definition of "waters of the United States" ~~(WOTUS) under the CWA. The WOTUS definition~~ is fundamental to the application of the CWA because only those bodies of water designated as WOTUS are protected from unlawful discharge of pollutants under the CWA.

In May 2023, the U.S. Supreme Court issued a decision defining WOTUS under the CWA and providing nationwide clarity of the federal government’s jurisdiction over WOTUS. The decision restricts the federal government's ability to regulate wetlands that do not have a continuous surface connection with a navigable water. While not addressed in the opinion, ephemeral streams and other water bodies that are not relatively permanent would also not be jurisdictional under the May 2023 ~~decision.~~decision. The ~~current presidential administration is developing a rule to amend the previous rule published in January 2023, consistent with the U.S. Supreme Court's decision. Because the~~ new definition ~~does~~of WOTUS from the Supreme Court should not alter how the CWA applies to most of Idaho Power's facilities, including its hydropower ~~plants,~~plants. As a result, Idaho Power does not expect the new ~~rule~~definition to materially impact Idaho Power's operations or financial condition.

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),~~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 associated with those permitting and compliance 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 costs associated with the relicensing of its ~~hydroelectric~~hydropower facilities, as discussed elsewhere in this report.

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 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~~ten of the dams ~~and~~and anticipates completing all submissions by June 2024.

Invasive Species Management

Quagga mussels are an invasive species which have not been present in the Snake River system historically. Quagga mussel infestations can foul up irrigation, hydropower, and water delivery facilities and increase the costs to maintain such facilities. In September 2023, a larval form of quagga mussels and one adult quagga mussel were detected in the mid-Snake River near Twin Falls in Idaho Power's service area by the Idaho State Department of Agriculture (ISDA). As a result, in October 2023, ISDA treated approximately six miles of the Snake River, which includes Idaho Power's Twin Falls and Shoshone Falls hydropower facilities, using a copper-based, EPA-approved treatment called Natrix to eradicate quagga mussels.

If the treatment is unsuccessful, and a quagga mussel infestation occurs, it may result in increased other O&M costs for mitigation efforts and other adverse impacts for Idaho Power's operation of its hydropower facilities in any infested areas. As of the date of this report, Idaho Power cannot predict the extent to which the Natrix treatment will be successful in eradicating

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quagga mussels from the Snake River, the extent of the treatment’s impact to the river and its inhabitants, or the potential increase in other O&M expenses related to quagga mussel mitigation efforts.

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 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, 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~~September 30, 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~~September 30, 2023, IDACORP had no net variable rate debt, as the carrying value of short-term investments exceeded the carrying value of outstanding variable rate debt.

Fixed Rate Debt: As of ~~June~~September 30, 2023, IDACORP had ~~$2.5~~$2.8 billion in fixed rate debt, with a fair value of approximately ~~$2.2~~$2.4 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 ~~$278~~$297 million if market interest rates were to decline by one percentage point from their ~~June~~September 30, 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 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~~September 30, 2023, had not changed materially from that reported in Item 7A of ~~IDACORP's and Idaho Power's~~the 2022 Annual ~~Report on Form 10-K for the year ended December 31, 2022 (2022 Annual Report).~~Report. Information regarding Idaho Power’s use of derivative instruments to manage commodity price risk can be found in Note 11 - "Derivative Financial Instruments" to the condensed consolidated financial statements included in this report.

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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~~September 30, 2023, Idaho Power posted ~~$44~~$29 million of 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 then-existing market conditions, as of ~~June~~September 30, 2023, the amount of additional collateral that could behave been requested upon a downgrade to below investment grade was approximately ~~$18.7~~$10 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~~September 30, 2023, had not changed materially from that reported in Item 7A of the 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 11 - "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 11 - "Benefit Plans" to the consolidated financial statements included in the 2022 Annual Report.

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~~September 30, 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~~September 30, 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~~September 30, 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

~~None~~None.

SEC regulations require IDACORP and Idaho Power to disclose certain information about proceedings arising under federal, state or local environmental provisions if the companies reasonably believe that such proceedings may result in monetary sanctions above a stated threshold. Pursuant to the SEC regulations, the companies use a threshold of $1 million or more for purposes of determining whether disclosure of any such proceedings is required.

ITEM 1A. RISK FACTORS

The factors discussed in Part I - Item 1A - "Risk Factors" in ~~IDACORP's and Idaho Power's~~the 2022 Annual Report, ~~on Form 10-K for the year ended December 31, 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, AND
ISSUER PURCHASES OF EQUITY SECURITIES

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~~September 30, 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

During the three months ended ~~June~~September 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~~terminated 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~~S-K). During the three months ended September 30, 2023, neither IDACORP nor Idaho Power adopted or terminated a Rule 10b5-1 trading arrangement (as such term is defined in Item 408 of ~~the Securities Act of 1933)~~Regulation S-K).

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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~~September 30, 2023:

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 3,~~November 2, 2023	By:	/s/ Lisa A. Grow
			Lisa A. Grow
			President and Chief Executive Officer

Date:	~~August 3,~~November 2, 2023	By:	/s/ Brian R. Buckham
			Brian R. Buckham
			Senior Vice President and Chief Financial Officer






		IDAHO POWER COMPANY
		(Registrant)



Date:	~~August 3,~~November 2, 2023	By:	/s/ Lisa A. Grow
			Lisa A. Grow
			President and Chief Executive Officer

Date:	~~August 3,~~November 2, 2023	By:	/s/ Brian R. Buckham
			Brian R. Buckham
			Senior Vice President and Chief Financial Officer

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