\n\u00a0<\/p>\n<\/td>\n
\n\u00a0<\/p>\n<\/td>\n
Three months ended<\/b><\/p>\n
June 30,<\/b><\/p>\n<\/td>\n
\n\u00a0<\/p>\n<\/td>\n
Six months ended<\/b><\/p>\n
June 30,<\/b><\/p>\n<\/td>\n<\/tr>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n 2026<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n 2025<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n 2026<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n 2025<\/b><\/p>\n<\/td>\n<\/tr>\n \nNet income attributable to IDACORP, Inc.<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n102,577<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n95,781<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n170,558<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n155,428<\/p>\n<\/td>\n<\/tr>\n \nWeighted average outstanding shares \u2013 diluted<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n57,229<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n54,380<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n56,767<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n54,249<\/p>\n<\/td>\n<\/tr>\n \nIDACORP, Inc. earnings per diluted share<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n1.79<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n1.76<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n3.00<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$<\/p>\n<\/td>\n \n2.87<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nThe table below provides a reconciliation of net income attributable to IDACORP for the three months and six months ended June 30, 2026, from the same periods in 2025 (items are in millions of dollars and are before related income tax impact unless otherwise noted):<\/p>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n Three months ended<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n Six months ended<\/b><\/p>\n<\/td>\n<\/tr>\n Net income attributable to IDACORP, Inc. – June 30, 2025<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n $<\/b><\/p>\n<\/td>\n 95.8<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n $<\/b><\/p>\n<\/td>\n 155.4<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nIncrease (decrease) in Idaho Power net income:<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nRetail revenues per megawatt-hour (MWh), excluding large contract customers, net of power cost adjustment mechanisms<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n27.5<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n44.0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nCustomer growth, excluding large contract customers, net of associated power supply costs and power cost adjustment mechanisms<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n4.5<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n8.2<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nUsage per retail customer, excluding large contract customers, net of associated power supply costs and power cost adjustment mechanisms<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(0.1<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(12.4<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nIdaho fixed cost adjustment (FCA) revenues<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n2.7<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n21.8<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nRetail revenues from large contract customers, net of associated power supply costs and the Idaho-jurisdiction power cost adjustment (PCA) mechanism<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n6.5<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n8.9<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nOther operations and maintenance (O&M) expenses<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(11.7<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(24.8<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nDepreciation and amortization expense<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(5.2<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(10.9<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nOther changes in operating revenues and expenses, net<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n6.3<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n22.0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nIncrease in Idaho Power operating income<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n30.5<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n56.8<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nNon-operating expense, net<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(0.5<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(4.6<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nAdditional accumulated deferred investment tax credits (ADITC) amortization<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(17.2<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(30.2<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nIncome tax expense, excluding additional ADITC amortization<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(4.4<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(5.0<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nTotal increase in Idaho Power net income<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n8.4<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n17.0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n \nOther IDACORP changes (net of tax)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(1.6<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n(1.8<\/p>\n<\/td>\n \n)<\/p>\n<\/td>\n<\/tr>\n Net income attributable to IDACORP, Inc. – June 30, 2026<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n $<\/b><\/p>\n<\/td>\n 102.6<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n $<\/b><\/p>\n<\/td>\n 170.6<\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Net Income – Second Quarter 2026<\/i><\/b><\/p>\n \nIDACORP’s net income increased $6.8 million for the second quarter of 2026 compared with the second quarter of 2025, due primarily to higher net income at Idaho Power.<\/p>\n \nThe net increase in retail revenues per MWh, excluding large contract customers, and net of power cost adjustment mechanisms, increased operating income by $27.5 million in the second quarter of 2026 compared with the second quarter of 2025. This benefit was due primarily to an overall increase in Idaho base rates, effective January 1, 2026, from the outcome of the settlement stipulation for Idaho Power’s 2025 Idaho general rate case (2025 Settlement Stipulation).<\/p>\n \nCustomer growth, excluding large contract customers, and net of associated power supply costs and power cost adjustment mechanisms, increased operating income by $4.5 million in the second quarter of 2026 compared with the second quarter of 2025, as the number of Idaho Power customers grew by approximately 15,000, or 2.3 percent, during the twelve months ended June 30, 2026. Usage per retail customer, excluding large contract customers, and net of associated power supply costs and power cost adjustment mechanisms, was relatively consistent in the second quarter of 2026 compared with the second quarter of 2025, as a 2 percent decrease in usage per residential customer was mostly offset by an increase in usage per customer for irrigation customers. A decrease in the deferral of residential and small commercial customer revenues through the FCA mechanism positively affected retail revenues by $2.7 million.<\/p>\n \nRetail revenues from large contract customers, net of associated power supply costs and the PCA mechanism, increased operating income by $6.5 million in the second quarter of 2026 compared with the second quarter of 2025. This benefit was primarily due to an increase in usage per large contract customer, the overall increase in Idaho base rates effective January 1, 2026, and the addition of one new large contract effective June 1, 2026.<\/p>\n \nOther O&M expenses in the second quarter of 2026 were $11.7 million higher than the second quarter of 2025. This increase was primarily the result of previously deferred costs related to the conversion of generating units at the Jim Bridger plant from coal to natural gas, much of which is recovered in customer rates and reflected in revenues pursuant to the 2025 Settlement Stipulation. The amortization of previously deferred wildfire mitigation program expenses, which are also recovered in customer rates and reflected in revenues for both the Idaho and Oregon jurisdictions, also contributed to the increase from the second quarter of 2025.<\/p>\n \nDepreciation and amortization expense increased $5.2 million in the second quarter of 2026 compared with the second quarter of 2025, due primarily to an increase in plant-in-service.<\/p>\n \nOther changes in operating revenues and expenses, net, increased operating income by $6.3 million in the second quarter of 2026 compared with the second quarter of 2025, due primarily to a decrease in net power supply expenses that were not accrued for future refund in rates through Idaho Power’s power cost adjustment mechanisms. Also contributing to the increase in other changes in operating revenues and expenses, net, was a decrease in property tax expense due to property tax legislative changes in Idaho.<\/p>\n \nNon-operating expense, net, increased $0.5 million in the second quarter of 2026 compared with the second quarter of 2025. Higher long-term debt balances led to an increase in interest expense, while lower interest-bearing cash investments led to a decrease in interest income. This increase was mostly offset by an increase in Allowance for Funds Used During Construction (AFUDC) in the second quarter of 2026 compared with the second quarter of 2025, as the average construction work in progress balance was higher.<\/p>\n \nThe increase in income tax expense for the second quarter of 2026, compared with the second quarter of 2025, was primarily due to a decrease in additional ADITC amortization under the Idaho regulatory settlement stipulation and an increase in pre-tax income. Based on Idaho Power’s current expectations of full-year 2026 financial results, Idaho Power recorded no additional ADITC amortization during the second quarter of 2026, compared with $17.2 million of additional ADITC amortization during the second quarter of 2025.<\/p>\n Net Income – Year-To-Date 2026<\/i><\/b><\/p>\n \nIDACORP’s net income increased $15.2 million for the first six months of 2026 compared with the first six months of 2025, due primarily to higher net income at Idaho Power.<\/p>\n \nThe net increase in retail revenues per MWh, excluding large contract customers, and net of power cost adjustment mechanisms, increased operating income by $44 million in the first six months of 2026 compared with the first six months of 2025. This benefit was due primarily to an overall increase in Idaho base rates, effective January 1, 2026, from the outcome of the 2025 Settlement Stipulation.<\/p>\n \nCustomer growth, excluding large contract customers, and net of associated power supply costs and power cost adjustment mechanisms, increased operating income by $8.2 million in the first six months of 2026 compared with the first six months of 2025. Usage per retail customer, excluding large contract customers, and net of associated power supply costs and power cost adjustment mechanisms, decreased operating income by $12.4 million in the first six months of 2026 compared with the first six months of 2025. Residential usage per customer decreased most significantly, as more moderate temperatures in the first six months of 2026 compared with the first six months of 2025 led residential customers to use less energy for heating and cooling purposes. A decrease in the deferral of residential and small commercial customer revenues through the FCA mechanism positively affected retail revenues by $21.8 million.<\/p>\n \nRetail revenues from large contract customers, net of associated power supply costs and the PCA mechanism, increased operating income by $8.9 million in the first six months of 2026 compared with the first six months of 2025. This change was primarily due to an increase in usage per large contract customer, the overall increase in Idaho base rates effective January 1, 2026, and the addition of one new large contract effective June 1, 2026.<\/p>\n \nOther O&M expenses in the first six months of 2026 were $24.8 million higher than the first six months of 2025. This increase was primarily the result of previously deferred costs related to the conversion of generating units at the Jim Bridger plant from coal to natural gas, much of which is recovered in customer rates and reflected in revenues pursuant to the 2025 Settlement Stipulation. The amortization of previously deferred wildfire mitigation program expenses, which are also recovered in customer rates and reflected in revenues for both the Idaho and Oregon jurisdictions, also contributed to the increase from the first six months of 2025.<\/p>\n \nDepreciation and amortization expense increased $10.9 million for the first half of 2026 compared with the first half of 2025, due primarily to an increase in plant-in-service.<\/p>\n \nOther changes in operating revenues and expenses, net, increased operating income by $22.0 million in the first six months of 2026 compared with the first six months of 2025, due primarily to a decrease in net power supply expenses that were not accrued for future refund in rates through Idaho Power’s power cost adjustment mechanisms. Also contributing to the increase in other changes in operating revenues and expenses, net, was a decrease in property tax expense due to property tax legislative changes in Idaho.<\/p>\n \nNon-operating expense, net, increased $4.6 million in the first six months of 2026 compared with the first six months of 2025. Higher long-term debt balances led to an increase in interest expense. This increase was partially offset by an increase in AFUDC in the first six months of 2026 compared with the first six months of 2025, as the average construction work in progress balance was higher. In addition, interest income decreased due to lower cash and cash equivalent balances in the first six months of 2026 compared with the first six months of 2025.<\/p>\n \nThe increase in income tax expense was principally the result of a decrease in additional ADITC amortization and higher pre-tax income. Based on Idaho Power’s current expectations of full-year 2026 financial results, Idaho Power recorded $6.3 million of additional ADITC amortization under its Idaho regulatory settlement stipulation during the first six months of 2026, compared with $36.5 million of additional ADITC amortization during the same period in 2025.<\/p>\n Annual Earnings Guidance and Key Operating and Financial Metrics<\/b><\/p>\n \nIDACORP is increasing the lower-end of its earnings guidance estimate for 2026. The 2026 guidance incorporates all of the key operating and financial assumptions listed in the table that follows (in millions of dollars or MWh, except per share amounts):<\/p>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n Current(1)<\/sup><\/b><\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n Prior(2)<\/sup><\/b><\/p>\n<\/td>\n<\/tr>\n \nIDACORP Earnings Guidance (per diluted share)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$ 6.30 \u2013 $ 6.45<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$ 6.25 \u2013 $ 6.45<\/p>\n<\/td>\n<\/tr>\n \nIdaho Power additional ADITC amortization<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \nLess than $ 15<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \nLess than $ 30<\/p>\n<\/td>\n<\/tr>\n \nIdaho Power O&M Expense<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \nNo Change<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$ 525 \u2013 $ 535<\/p>\n<\/td>\n<\/tr>\n \nIdaho Power Capital Expenditures, Excluding AFUDC<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \nNo Change<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n$ 1,300 \u2013 $ 1,500<\/p>\n<\/td>\n<\/tr>\n \nIdaho Power Hydropower Generation (MWh)<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n5.5 \u2013 6.5<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n5.5 \u2013 7.0<\/p>\n<\/td>\n<\/tr>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n<\/tr>\n (1) <\/sup>As of July 30, 2026. Assumes normal weather conditions through the end of 2026.<\/p>\n<\/td>\n<\/tr>\n (2) <\/sup>As of April 30, 2026, the date of filing IDACORP’s and Idaho Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2026.<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nMore detailed financial and operational information is provided in IDACORP\u2019s Quarterly Report on Form 10-Q filed today with the U.S. Securities and Exchange Commission, which is also available for review on IDACORP\u2019s website at idacorpinc.com.<\/p>\n Web Cast \/ Conference Call<\/b><\/p>\n \nIDACORP will hold an analyst conference call today at 2:30 p.m. Mountain Time (4:30 p.m. Eastern Time). All parties interested in listening may do so through a live webcast on IDACORP’s website (idacorpinc.com), or by calling (855) 761-5600 for listen-only mode. The passcode for the call is 9290150. The conference call logistics are also posted on IDACORP’s website. Slides will be included during the conference call. To access the slide deck, please visit idacorpinc.com\/investor-relations. A replay of the conference call will be available on the company’s website for 12 months and will be available shortly after the call.<\/p>\n Background Information<\/b><\/p>\n \nIDACORP, Inc. (NYSE: IDA), Boise, Idaho-based and formed in 1998, is a holding company comprised of Idaho Power, a regulated electric utility; IDACORP Financial, an investor in affordable housing and other real estate tax credit investments; and Ida-West Energy, an operator of small hydroelectric generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978. Idaho Power, headquartered in vibrant and fast-growing Boise, Idaho, has been a locally operated energy company since 1916. Today, it serves a 24,000-square-mile service area in Idaho and Oregon. With 17 low-cost hydropower projects at the core of its diverse energy mix, Idaho Power\u2019s residential, business, and agricultural customers pay among the nation’s lowest prices for electricity. Its nearly 2,200 employees proudly serve more than 670,000 customers with a culture of safety first, integrity always, and respect for all. To learn more about IDACORP or Idaho Power, visit idacorpinc.com or idahopower.com.<\/p>\n Forward-Looking Statements<\/b><\/p>\n \nIn addition to the historical information contained in this press release, this press release 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, power generation, cash flows, capital expenditures, regulatory filings, 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,” or similar expressions, are not statements of historical facts and may be forward-looking. Forward-looking statements are not guarantees of future performance, involve estimates, assumptions, risks, and uncertainties, 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 press release, IDACORP’s and Idaho Power’s most recent Annual Report on Form 10-K, particularly Part I, Item 1A – “Risk Factors” and Part II, Item 7 – “Management\u2019s Discussion and Analysis of Financial Condition and Results of Operations” of that report, subsequent reports filed by IDACORP and Idaho Power with the U.S. Securities and Exchange Commission (SEC), and the following important factors: (a) decisions or actions by the Idaho and Oregon public utilities commissions and the Federal Energy Regulatory Commission that impact Idaho Power’s ability to recover costs and earn a return on investment; (b) changes to or the elimination of Idaho Power’s regulatory cost recovery mechanisms; (c) expenses and risks associated with capital expenditures and contractual obligations for, and the permitting and construction of, utility infrastructure projects that Idaho Power may be unable to complete, are delayed, have cost increases due to tariffs, supply chain constraints, or other factors, or that may not be deemed prudent by regulators for cost recovery or return on investment; (d) expenses and risks associated with supplier and contractor delays and failure to satisfy project quality and performance standards on utility infrastructure projects, including as a result of tariffs, supply chain constraints, permitting requirements and limitations, and the potential impacts of those delays and failures on Idaho Power’s ability to serve customers and generate revenues; (e) the rapid addition of new industrial customer load, uncertainty of forecasted power usage ramp rates or volumes, and the volatility and timing of that new load demand and revenues, resulting in increased risks of power demand potentially exceeding available supply and revenue, cash flow, and earnings volatility; (f) impacts of economic conditions, including an inflationary or recessionary environment and 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 on the timing and extent of counterparties\u2019 power usage, and collection of receivables; (g) changes in residential, commercial, irrigation, and industrial growth and demographic patterns within Idaho Power’s service area, and the associated impacts on loads and load growth; (h) 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; (i) changes in, failure to comply with, and costs of compliance with laws, regulations, policies, orders, federal grants, and licenses, which may result in penalties and fines, increase compliance and operational costs, and impact recovery associated with increased costs through rates; (j) abnormal or severe weather conditions, wildfires, droughts, earthquakes, and other natural phenomena and natural disasters, which affect customer sales, hydropower generation, repair costs, service interruptions, public safety power shutoffs and de-energization, liability for damage caused by utility property, and the availability and cost of fuel for generation plants or purchased power to serve customers; (k) advancement and adoption 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; (l) 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 and power supply costs; (m) ability to acquire equipment, materials, fuel, power, and transmission capacity on reasonable terms and prices, particularly in the event of unanticipated or abnormally high resource demands, price volatility (including as a result of new or increased tariffs), lack of physical availability, transportation constraints, outages due to maintenance or repairs to generation or transmission facilities, disruptions in the supply chain, or reduced credit quality or lack of counterparty and supplier credit; (n) 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; (o) 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, increased power supply costs and repair expenses, and reduced revenues; (p) accidents, electrical contacts, fires (either affecting or caused by Idaho Power facilities or infrastructure), explosions, infrastructure failures, general system damage or dysfunction, and other unplanned events that may occur while operating and maintaining assets, which can cause unplanned outages; reduce generating output; damage company assets, operations, or reputation; subject Idaho Power to third-party claims for property damage, personal injury, loss of life, or other losses; or result in the imposition of fines and penalties; (q) acts or threats of terrorism, 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\u2019 business, operations, or reputation resulting from such events; (r) Idaho Power’s concentration in one region, and the resulting exposure to regional economic conditions and regional legislation and regulation; (s) unaligned goals and positions with co-owners of Idaho Power\u2019s existing and planned generation and transmission assets that may adversely impact Idaho Power\u2019s ability to construct and operate those facilities in a manner most suitable to Idaho Power; (t) 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 expected tax credits or other tax benefits; (u) 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 rates, decisions by the state public utility commissions, and the companies’ past or projected financial performance; (v) 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 and cash flow impacts the companies may incur on those hedges; (w) changes in actuarial assumptions, changes in interest rates, and the actual and projected return on plan assets for pension and other postretirement plans, which can affect future pension and other postretirement plan funding obligations, costs, and liabilities and the companies’ cash flows; (x) remediation costs associated with planned cessation of coal-fired operations at Idaho Power’s co-owned coal plant; (y) ability to continue to pay dividends and achieve target dividend payout ratios based on financial performance and capital requirements, and in light of credit rating considerations, contractual covenants and restrictions, cash flows, and regulatory limitations; and (z) 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 the companies to predict all such factors, nor can they 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.<\/p>\n View source version on businesswire.com: <\/span>https:\/\/www.businesswire.com\/news\/home\/20260730346160\/en\/<\/a><\/span><\/p>\n Investor and Analyst Contact Media Contact KEYWORDS:<\/b> Idaho United States North America<\/p>\n INDUSTRY KEYWORDS:<\/b> Energy Other Energy Utilities<\/p>\n\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n
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John R. Wonderlich
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Investor Relations Manager
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Phone: (208) 388-5413
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JWonderlich@idahopower.com<\/a><\/p>\n
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Jordan Rodriguez
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Corporate Communications
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Phone: (208) 388-2460
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JRodriguez@idahopower.com<\/a><\/p>\n
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