IDACORP INC

Condensed Consolidated Statements of Income

Condensed Consolidated Statements of Comprehensive Income

Condensed Consolidated Statements of Cash Flows

Condensed Consolidated Statements of Equity

Condensed Consolidated Statements of Income

Condensed Consolidated Statements of Comprehensive Income

Condensed Consolidated Statements of Cash Flows

IDACORP, INC. AND IDAHO POWER COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

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

Nature of Business

IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sale, and purchase of electric energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. On February 13, 2026, Idaho Power signed an asset purchase agreement with OTEC for the sale of Idaho Power's electric distribution business and certain transmission assets in the state of Oregon. Refer to Note 16 - "Assets Held For Sale" for additional information regarding the Oregon Sale. Idaho Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the FERC. Idaho Power is the parent of IERCo, a joint-owner of BCC, which mines and supplies coal to the Jim Bridger plant owned in part by Idaho Power.

IDACORP’s other notable subsidiaries include IFS, an investor in affordable housing and other real estate tax credit investments, and Ida-West, an operator of small PURPA-qualifying hydropower generation projects.

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 entity 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 September 30, 2026, condensed consolidated statements of income for the three months and nine months ended September 30, 2026 and 2025, and condensed consolidated statements of cash flows for the nine months ended September 30, 2026 and 2025. 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 the 2025 Annual 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 GAAP. These estimates and assumptions include, among others, those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled receivables, and the allowance for uncollectible accounts. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments with respect to, among other things, future economic factors that are difficult to predict and are beyond management's control. Accordingly, actual results could differ from those estimates.

New and Recently Adopted Accounting Pronouncements

Recently Adopted Accounting Pronouncements

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

Recently Issued Accounting Pronouncements Not Yet Adopted

In May 2026, the FASB issued Accounting Standards Update (ASU) 2026-02, Environmental Credits and Environmental Credit Obligations, which establishes accounting requirements for environmental credits and environmental obligations, including their recognition, measurement, presentation, and disclosure. This ASU is effective for annual and interim periods beginning after December 15, 2027, with early adoption permitted. The provisions of this ASU are required to be applied retrospectively. IDACORP and Idaho Power are currently evaluating the impact that adoption of this ASU will have on their respective condensed consolidated financial statements.

Other than those described in Note 1 - "Summary of Significant Accounting Policies" to the consolidated financial statements included in the 2025 Annual Report and discussed above, there have been no additional recently issued accounting pronouncements that have not yet been adopted and 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 (benefit) (in thousands of dollars):

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

Supplemental Disclosure of Cash Flow Information

Supplemental cash flow information related to income taxes, including cash (refunded) paid for income taxes and cash received from IDACORP related to income taxes, is presented below (in thousands of dollars):

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 Rate Cases

Idaho Power's current base rates result from the IPUC and OPUC orders described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2025 Annual Report.

Idaho ADITC Mechanism

The 2018 Settlement Stipulation, 2023 Settlement Stipulation, and 2025 Settlement Stipulation are each described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2025 Annual Report. The 2025 Settlement Stipulation and the 2023 Settlement Stipulation modified the 2018 Settlement Stipulation in part. The 2023 Settlement Stipulation included provisions for the accelerated amortization of ADITCs to help achieve a minimum 9.12 percent Idaho ROE, while the 2025 Settlement Stipulation established an annual cap of $55 million on the amount of accelerated amortization of ADITCs for calendar year 2026 and thereafter and also modified the ADITC mechanism to include an additional amount of investment tax credits equal to the total of existing ADITCs not previously eligible for accelerated amortization under the mechanism and all investment tax credits generated through the end of calendar-year 2028.

Based on its estimate of full-year 2026 Idaho ROE, for the three months and nine months ended September 30, 2026, Idaho Power recorded zero and $6.3 million, respectively, in additional ADITC amortization under the 2025 Settlement Stipulation. Accordingly, as of September 30, 2026, approximately $154 million of additional ADITCs remained available for future use. Idaho Power recorded $2.5 million and $39.0 million, respectively, of additional ADITC amortization for the three months and nine months ended September 30, 2025, based on its then-current estimate of full-year 2025 Idaho ROE.

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 accrued as a credit on the balance sheets for future recovery or refund. The power supply costs deferred or accrued primarily result from changes in the levels of Idaho Power's own power generation, changes in contracted power purchase prices and volumes, changes in wholesale market prices and transaction volumes, and changes in fuel prices.

In May 2026, the IPUC issued an order approving a $51.3 million increase in PCA revenues as compared with the prior collection period, effective for the 2026-2027 PCA collection period from June 1, 2026 to May 31, 2027. The increase in PCA revenues is due primarily to a decrease in forecast hydroelectric generation for the April 2026 to March 2027 forecast period.

In May 2026, the OPUC approved a settlement stipulation between Idaho Power and intervening parties for its annual power cost adjustment mechanism in Oregon. The filing also requested recovery of 2025 incremental deferred wildfire mitigation costs. The settlement resulted in an increase of $1.9 million in Oregon-jurisdictional rates, effective June 1, 2026.

In May 2026, the OPUC approved a settlement stipulation between Idaho Power and intervening parties for its APCU in Oregon, resulting in an increase of $0.7 million in Oregon-jurisdictional revenues, effective June 1, 2026.

Idaho Fixed Cost Adjustment Mechanism

The 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 charge and linking it instead to a set amount per customer. Under Idaho Power's current rate design, recovery of a portion of fixed costs is included in the variable kilowatt-hour 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 2026, the IPUC issued an order approving Idaho Power's recovery of its 2025 FCA balance of $2.0 million, reflecting an increase in recovery from the FCA of $5.1 million as compared to the 2024 FCA regulatory liability balance of $3.1 million, over the period from June 1, 2026 to May 31, 2027.

Wildfire Mitigation Cost Recovery

The 2025 Settlement Stipulation authorized Idaho Power to defer certain incremental O&M and insurance costs for wildfire mitigation efforts above the 2024 base through the earlier of the next general rate case or 2027. As of September 30, 2026, Idaho Power’s deferral balance of Idaho-jurisdiction costs related to the WMP was $90.8 million, of which $65.1 million is approved to be amortized and currently collected in Idaho rates.

In December 2025, Idaho Power filed an application with the OPUC requesting authorization to defer for future recovery an estimated $3.1 million of newly identified incremental costs expected to be incurred in 2026 associated with expanded wildfire mitigation efforts. In September 2026, the OPUC approved the application. As of September 30, 2026, Idaho Power’s deferral balance of Oregon-jurisdiction costs related to the WMP was $3.2 million, of which $2.0 million is approved to be amortized and currently collected in Oregon rates.

4. REVENUES

The following table provides a summary of electric utility operating revenues for IDACORP and Idaho Power (in thousands of dollars):

Revenues from Contracts with Customers

The following table presents revenues from contracts with customers disaggregated by revenue source (in thousands of dollars):

(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 AFUDC on construction work in progress related to the HCC relicensing process in its Idaho jurisdiction, even though the relicensing process is not yet complete and the costs have not been moved to utility plant in service. Effective October 1, 2025, Idaho Power began collecting $38.5 million annually. Prior to October 1, 2025, Idaho Power collected $8.8 million annually. For more information refer to Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2025 Annual Report. Amounts collected in the Idaho jurisdiction are recognized as deferred revenue 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 FCA mechanism, which may increase or decrease tariff-based retail customer rates. The 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.

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."

The table below presents the FCA mechanism revenues and other revenues (in thousands of dollars):

Receivables and Allowance for Uncollectible Accounts

The following table provides a rollforward of the allowance for uncollectible accounts related to customer receivables (in thousands of dollars):

5. LONG-TERM DEBT

Long-Term Debt Issuances, Maturities, and Redemptions

On February 27, 2026, Idaho Power issued $350 million in aggregate principal amount of 4.85% first mortgage bonds, secured medium-term notes, Series O, maturing on March 1, 2036.

On July 15, 2026, Idaho Power repaid $116 million in aggregate principal amount of maturing 1.70% pollution control revenue bonds.

On August 6, 2026, Idaho Power issued $200 million in aggregate principal amount of its 5.70% first mortgage bonds, secured medium-term notes, Series O, maturing on March 15, 2055. The bonds were issued at a reoffer yield of 6.133%, which resulted in net proceeds to Idaho Power of $186.6 million plus accrued interest. After this offering the aggregate principal amount of the 5.70% first mortgage bonds is $600 million.

Idaho Power First Mortgage Bonds

Idaho Power's issuance of long-term indebtedness is subject to the approval of the IPUC, OPUC, and WPSC. In June and July 2026, Idaho Power received orders from the IPUC, OPUC, and WPSC authorizing the company to issue and sell from time to time up to $1.5 billion in aggregate principal amount of debt securities and first mortgage bonds, subject to conditions specified in the orders. Authority from the IPUC is effective through June 30, 2029, subject to extensions upon request to the IPUC. The OPUC's and WPSC's orders do not impose a time limitation for issuances, but the OPUC order does impose a number of other conditions, including a requirement that the interest rates for the debt securities or first mortgage bonds fall within either (a) designated spreads over comparable U.S. Treasury rates or (b) a maximum interest rate limit of 8 percent. At September 30, 2026, $1.3 billion remained available for debt issuance under the regulatory orders.

Idaho Power's Indenture of Mortgage and Deed of Trust, dated as of October 1, 1937, as amended and supplemented from time to time (Indenture), limits the amount of additional first mortgage bonds that Idaho Power may issue to the sum of (a) the principal amount of retired first mortgage bonds and (b) 60 percent of total unfunded property additions, as defined in the Indenture. As of September 30, 2026, the maximum amount of additional first mortgage bonds Idaho Power could issue under this test was approximately $2.4 billion. The Indenture also imposes a fixed cap of $5.5 billion on the aggregate amount of first mortgage bonds that may be outstanding under the Indenture, which cap may be amended under certain conditions. As of September 30, 2026, Idaho Power could issue approximately $1.6 billion of additional first mortgage bonds under that aggregate cap.

6. COMMON STOCK

IDACORP Common Stock

During the nine months ended September 30, 2026, IDACORP issued an aggregate of 2,996,285 shares of common stock using original issuances of shares. IDACORP granted 71,855 restricted stock unit awards and issued 55,032 shares of common stock to employees pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan, and issued an additional 31,837 shares of common stock pursuant to director equity compensation plans. IDACORP issued 31,323 shares of common stock pursuant to the IDACORP, Inc. Dividend Reinvestment and Stock Purchase Plan and 3,226 shares pursuant to the Idaho Power Company Employee Savings Plan.

At-the-Market Offering Programs (2024 & 2026 ATM Series): On May 15, 2026, IDACORP entered into an Equity Distribution Agreement pursuant to which it may issue, offer, and sell, from time to time, up to an aggregate gross sales price of $600 million of shares of its common stock through the 2026 ATM, which includes the ability to enter into FSAs. At September 30, 2026, IDACORP had $66.5 million of remaining capacity under its 2026 ATM. Before the 2026 ATM became effective, IDACORP had available the 2024 ATM providing for the sale of up to an aggregate gross sales price of $300 million of shares of its common stock. Upon effectiveness of the 2026 ATM, the 2024 ATM terminated with respect to new issuances.

During the nine months ended September 30, 2026, IDACORP executed FSAs under its 2024 ATM and 2026 ATM with various counterparties who borrowed and sold 4,926,437 shares of IDACORP’s common stock at an aggregate gross sales price of $689.0 million, including approximately $7.0 million in commissions and fees payable by IDACORP to the counterparties upon settlement.

At September 30, 2026, IDACORP had the following FSAs outstanding under its 2024 ATM and 2026 ATM (in thousands of dollars, except for shares and forward prices):

The FSAs will be physically settled with common shares issued by IDACORP, unless IDACORP elects to settle the agreements in net cash or net shares, subject to certain conditions. On a settlement date or dates, if IDACORP elects to physically settle the FSAs, IDACORP will issue shares of common stock to the various counterparties at the then-applicable forward sale price and receive issuance proceeds at that time.

At September 30, 2026, IDACORP could have settled all its outstanding FSAs under the ATMs with physical delivery of 4,926,437 shares of common stock to the counterparties in exchange for cash of $684.5 million. At September 30, 2026, IDACORP could have settled the FSAs with net receipt from various counterparties of approximately $3.3 million of cash or approximately 26,319 shares of common stock, if IDACORP had elected to net cash or net share settle, respectively. The FSAs have been classified as an equity transaction because they are indexed to IDACORP’s common stock and the other requirements necessary for equity classification are met. As a result of the equity classification, no gain or loss will be recognized within earnings due to subsequent changes in the fair value of the FSAs.

During the nine months ended September 30, 2026, IDACORP settled the following FSAs (in thousands of dollars, except for settlement shares and forward settlement prices):

(1)Settlement of the FSAs is recognized in IDACORP’s equity on the settlement date.

Equity Forward Sale Agreements (2025 Series): On May 8, 2025, IDACORP announced a registered public offering of 4,504,505 shares of its common stock at a public offering price of $111.00 per share, for an aggregate amount of

$500.0 million. In conjunction with this offering, underwriters exercised an option to purchase 675,675 additional shares for an additional aggregate amount of $75.0 million. The 5,180,180 shares were sold by IDACORP to the underwriters under FSAs, which provide for settlement on a settlement date or dates to be specified at IDACORP’s discretion, but which is expected to occur on or prior to November 9, 2026. The forward sale price was initially $107.67 per share and is subject to certain adjustments in accordance with the terms of the FSAs through the date or dates of settlement.

The FSAs will be physically settled with common shares issued by IDACORP, unless IDACORP elects to settle the agreements in net cash or net shares, subject to certain conditions. On a settlement date or dates, if IDACORP elects to physically settle the FSAs, IDACORP will issue shares of common stock to the various counterparties at the then-applicable forward sale price and receive issuance proceeds at that time.

During the nine months ended September 30, 2026, and subsequently through the date of this report, IDACORP settled the following FSAs under the 2025 Series (in thousands of dollars, except for settlement shares and forward settlement prices):

(1)Settlement of the FSAs is recognized in IDACORP’s equity on the settlement date.

At September 30, 2026, IDACORP could have settled the remaining outstanding FSAs with physical delivery of 2,757,569 shares of common stock to the counterparties in exchange for cash of $297.7 million. The FSAs could have also been settled at September 30, 2026, with delivery of approximately $89.2 million of cash or approximately 634,702 shares of common stock to the counterparties, if IDACORP had elected to net cash or net share settle, respectively. The FSAs have been classified as an equity transaction because they are indexed to IDACORP’s common stock and the other requirements necessary for equity classification are met. As a result of the equity classification, no gain or loss will be recognized within earnings due to subsequent changes in the fair value of the FSAs.

FSA Earnings Per Share Dilution: Prior to settlement, the potentially issuable shares pursuant to the FSAs will be reflected in IDACORP’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of IDACORP’s common stock used in calculating diluted earnings per share for a reporting period would be increased by the number of shares, if any, that would be issued upon physical settlement of the FSAs, less the number of shares that could be purchased by IDACORP in the market with the proceeds received from issuance (based on the average market price during that reporting period). Share dilution occurs when the average market price of IDACORP’s stock during the reporting period is higher than the then-applicable forward sale price as of the end of the reporting period. For the three months and nine months ended September 30, 2026, approximately 758,000 and 1,074,000 incremental shares, respectively, were included in the calculation of diluted earnings per share related to the securities under the FSAs. For the three months and nine months ended September 30, 2025, approximately 744,000 and 311,000 incremental shares, respectively, were included in the calculation of diluted earnings per share related to the securities under the FSAs. See Note 7 - "Earnings Per Share" for additional information on IDACORP's diluted earnings per share.

Idaho Power Common Stock

During the three months and nine months ended September 30, 2026, IDACORP contributed $186.8 million and $376.8 million, respectively, of additional capital to Idaho Power. No additional shares of Idaho Power common stock were issued.

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 Statement of Policy and 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 September 30, 2026, the leverage ratios for IDACORP and Idaho Power, as defined in the credit facilities, were each 51 percent. Based on these restrictions, IDACORP’s and Idaho Power’s potential dividends were limited to $1.8 billion and $1.7 billion, respectively, at September 30, 2026. 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 September 30, 2026, IDACORP and Idaho Power were in compliance with those covenants.

Idaho Power’s Statement of 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 September 30, 2026, Idaho Power's common equity capital was 49 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 hasno 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 (in thousands of dollars or shares, except for per share amounts).

(1)Includes the effect of dilutive securities related to FSAs. See Note 6 - "Common Stock" for additional information on IDACORP's FSAs.

8. COMMITMENTS

Purchase Obligations

During the nine months ended September 30, 2026, Idaho Power entered into the following agreements:

•fuel-related agreements in April 2026, increasing its contractual purchase obligations by approximately $1.6 billion over a 15-year term, beginning May 2030 and expiring May 2045;

•an agreement in May 2026 to replace expiring PPAs with a PURPA-qualifying hydropower facility, which increased Idaho Power's contractual purchase obligations by approximately $10.3 million over the 20-year term commencing in September 2026;

•a 200 MW solar facility PPA and an agreement to purchase the storage capacity from a 100 MW battery storage facility, both executed in May 2026 with a scheduled online date of May 2028, which collectively increased Idaho Power's contractual purchase obligations by approximately $796.2 million over their 20-year terms;

•an agreement in June 2026 to acquire and own certain equipment and to receive related technical services, which increased Idaho Power's contractual purchase obligations by approximately $218.0 million through the first half of 2029; and

•an agreement in July 2026 to extend an expiring PPA with a wind facility, which increased Idaho Power's contractual purchase obligations by approximately $94.6 million over the 5-year term commencing in January 2028.

Except as discussed above, during the nine months ended September 30, 2026, 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 2025 Annual Report.

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 (WDEQ), was $49.7 million at September 30, 2026, representing IERCo's one-third share of BCC's total reclamation obligation of $149.2 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At September 30, 2026, the value of BCC's reclamation trust fund exceeded WDEQ's guarantee requirement for the total reclamation obligation. 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 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 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 September 30, 2026, management believes the likelihood is remote that IDACORP or Idaho Power would be required to perform under such indemnification provisions or otherwise incur any significant losses with respect to such indemnification obligations. Neither IDACORP nor Idaho Power has recorded any liability on their respective condensed consolidated balance sheets with respect to these indemnification obligations.

9. CONTINGENCIES

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

IDACORP and Idaho Power are parties to legal claims and legal, tax, and regulatory actions and proceedings in the ordinary course of business and, as noted above, record an accrual for associated loss contingencies when they are probable and reasonably estimable. In connection with its utility operations, Idaho Power is subject to claims by individuals, entities, and governmental agencies for damages for alleged personal injury, property damage, and economic losses, relating to the company’s provision of electric service, the operation of its power supply, transmission, and distribution facilities, and other aspects of its business. 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 actively monitors any pending or potential 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 any such regulations and orders.

10. BENEFIT PLANS

Idaho Power has the noncontributory defined benefit pension plan andtwo nonqualified defined benefit plans for certain senior management employees called the 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 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 September 30, 2026 and 2025 (in thousands of dollars).

(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, $9.8 million and $9.8 million, respectively, were recognized in "Other operations and maintenance" and $1.6 million and $1.5 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the three months ended September 30, 2026 and 2025.

(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, $29.1 million and $29.4 million, respectively, were recognized in "Other operations and maintenance" and $4.6 million and $4.5 million, respectively, were recognized in "Other income, net" on the condensed consolidated statements of income of the companies for the nine months ended September 30, 2026 and 2025.

Idaho Power has no minimum contribution to its pension plan required in 2026. During the nine months ended September 30, 2026, Idaho Power contributed $20 million 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.

11. DERIVATIVE FINANCIAL INSTRUMENTS

Commodity Price Risk

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

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

The table below presents the gains and losses on derivatives not designated as hedging instruments (in thousands of dollars):

(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 September 30, 2026, 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, bonds, 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.

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. 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 September 30, 2026, was $61.6 million. As of September 30, 2026, Idaho Power posted $47.8 million of cash collateral related to this amount. If the credit-risk-related contingent features underlying these agreements were triggered on September 30, 2026, Idaho Power would have been required to pay or post collateral to its counterparties up to an additional $34.4 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 (in thousands of dollars):

(1)Current liability derivative amounts offset include $32.7 million of collateral receivable at September 30, 2026.

(2)Long-term liability derivative amounts offset include $2.1 million of collateral receivable at September 30, 2026.

(3)Current liability derivative amounts offset include $26.9 million of collateral receivable at December 31, 2025.

(4)Long-term liability derivative amounts offset include $2.9 million of collateral receivable at December 31, 2025.

The table below presents the volumes of derivative commodity forward contracts and swaps outstanding (in thousands of units):

12. FAIR VALUE MEASUREMENTS

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

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

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

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

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

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

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

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

IDACORP and Idaho Power Level 2 inputs for derivative instruments are based on quoted market prices adjusted for location using corroborated, observable market data or using quoted 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 nine months ended September 30, 2026.

Certain instruments have been valued using 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.

The following table presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis (in thousands of dollars):

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

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

The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value, using available market information and appropriate valuation methodologies (in thousands of dollars).

(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 $2.5 million and $1.4 million as of September 30, 2026, and December 31, 2025, respectively. Substantially all of these debt securities mature between 2027 and 2038. 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 September 30, 2026, and December 31, 2025.

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 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 power supply, 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 investment.

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 consists 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.

IDACORP’s and Idaho Power’s chief operating decision maker is regularly provided with segment expense information for utility operations at the same level of detail as presented in Idaho Power’s condensed consolidated statements of income.

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 of dollars).

14. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

The table below presents changes in components of AOCI, net of tax (in thousands of dollars). Items in parentheses indicate charges to AOCI.

The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified (in thousands of dollars). Items in parentheses indicate increases to net income.

(1)Amortization of these items is included in IDACORP's condensed consolidated statements of income 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.

15. CHANGES IN IDAHO POWER RETAINED EARNINGS

The table below presents changes in Idaho Power retained earnings (in thousands of dollars).

16. ASSETS HELD FOR SALE

On February 13, 2026, Idaho Power executed a definitive asset purchase agreement to sell its Oregon electric distribution business as well as certain Oregon transmission assets to OTEC. The base purchase price to be paid by OTEC for the Oregon Sale is $154 million, and is subject to certain adjustments as of the closing of the transaction. Idaho Power has agreed to operate its Oregon electric distribution business and applicable transmission assets in the ordinary course of business and subject to certain operating covenants during the period between the date of the asset purchase agreement and the completion of the proposed transaction. Idaho Power also agreed to provide certain transition services to OTEC for a limited post-closing period for a fee. While Idaho Power expects the transaction to be completed within one year of September 30, 2026, the Oregon Sale is subject to various closing conditions, including approvals of the OPUC, IPUC, and FERC, as well as certain price adjustment and termination provisions.

Idaho Power determined that the assets and liabilities related to the Oregon Sale (disposal group) met the criteria for classification as held for sale as of September 30, 2026. Accordingly, the disposal group was reclassified to assets held for sale and liabilities held for sale, respectively, within the condensed consolidated balance sheets as of September 30, 2026. The disposal group is reported within IDACORP's Utility Operations reportable segment. See Note 13 - "Segment Information."

Upon reclassification, the disposal group was measured at the lower of its carrying amount or estimated fair value less costs to sell. As a result of this measurement, the fair value less costs to sell of the disposal group exceeds its net carrying amount as of September 30, 2026, and accordinglyno impairment loss has been recognized for the three months and nine months ended September 30, 2026. Any gain on the Oregon Sale will be recognized upon closing of the transaction. Because depreciation and amortization of the assets and liabilities included in the disposal group continue to be reflected in Oregon customer rates through closing of the transaction, Idaho Power will continue recording depreciation and amortization on the disposal group through that date.

The disposal group has not been classified as a discontinued operation and the historical results of the disposal group are included in the condensed consolidated statements of income for all periods presented.

The table below summarizes components of assets and liabilities in the disposal group classified as held for sale on the condensed consolidated balance sheets (in thousands of dollars):

(1)Total assets held for sale and total liabilities held for sale are presented within current assets and current liabilities, respectively, on the condensed consolidated balance sheets as of September 30, 2026, as the sale is expected to be completed within 12 months.

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 September 30, 2026, the related condensed consolidated statements of income, comprehensive income and equity for the three-month and nine-month periods ended September 30, 2026 and 2025, and of cash flows for the nine-month periods ended September 30, 2026 and 2025, 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, 2025, 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 19, 2026, 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, 2025, 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

October 29, 2026

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 September 30, 2026, the related condensed consolidated statements of income and comprehensive income for the three-month and nine-month periods ended September 30, 2026 and 2025, and of cash flows for the nine-month periods ended September 30, 2026 and 2025, 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, 2025, 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 19, 2026, 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, 2025, 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

October 29, 2026