IDACORP (IDA) Q2 2026 earnings review
Core Execution Shines as Regulatory Subsidies Drop to Zero
IDACORP delivered a high-quality Q2 earnings beat, breaking the narrative that massive infrastructure spending must compress near-term margins. EPS accelerated to $1.79 (up from $1.76), but the real story is under the hood: Idaho Power's operating income surged by $30.5M, allowing the company to record absolutely zero tax credit (ADITC) support during the quarter. This structural improvement prompted management to raise the lower end of full-year EPS guidance to $6.30 while drastically cutting its projected tax credit reliance. While the 'growth pays for growth' model is successfully absorbing the $1.4B annual CapEx cycle via higher base rates, investors must closely monitor escalating operational expenses and a macro-driven downgrade in hydropower generation.
🐂 Bull Case
The 2025 Settlement base rate hikes and robust large-contract additions generated $34M in combined Q2 operating income growth, completely offsetting higher capital costs without relying on regulatory tax credits.
The company's 'growth pays for growth' thesis is validating in real-time. Load from data centers and new contracts like Micron is funding systemic expansion while shielding residential base rates.
🐻 Bear Case
O&M expenses surged $11.7M in Q2 and $24.8M in H1. Wildfire mitigation and coal-to-gas conversion costs are structural headwinds eating into gross margins.
Milder weather actually reduced residential usage, creating a $12.4M drag on H1 operating income. Meanwhile, low snowpack forced a reduction in the annual hydropower generation forecast.
⚖️ Verdict: 🟢
Bullish. Delivering EPS growth while simultaneously collapsing reliance on ADITC tax credits indicates peak fundamental health, proving the regulatory strategy is perfectly matched to the hyper-growth CapEx cycle.
Key Themes
Earnings Quality Reversing ADITC Reliance
The defining metric of the quarter is the $0 ADITC tax credit amortization recorded in Q2 (down from $17.2M a year ago). For the first half, usage plummeted from $36.5M to just $6.3M. This reverses a multi-year trend of utilizing tax credits to prop up the ROE floor. The company has officially raised its floor of organic profitability, allowing it to preserve these credits for future, heavier CapEx years.
Rate Relief Absorbing Infrastructure Shock
The financial bridge balancing a $7B+, 5-year CapEx plan is holding strong. Retail revenues per MWh (net of power costs) injected $27.5M into Q2 operating income, directly driven by the January 1, 2026, base rate increases established in the 2025 Settlement. This proves management's regulatory execution is successfully synchronizing cash flows with rate base expansion.
Rapid BESS Deployment Validates Grid Modernization
IDACORP successfully brought 250 MW of battery energy storage systems (BESS) online in June 2026. This specific technological integration acts as critical firm capacity to support the volatile industrial load (Meta, Micron) while balancing intermittent solar/wind, keeping the company on track for its 2030 modernization milestones without grid destabilization.
Organic Volume Contradicted by Weather Drag
Despite management touting 'continued customer growth', the data reveals a contradiction in the core volume narrative. Usage per retail customer actually decreased H1 operating income by $12.4M due to moderate weather. The earnings beat is almost entirely reliant on fixed base rate hikes (+44M in H1) and massive FCA/regulatory protections (+21.8M in H1), masking organic volume weakness at the residential level.
Accelerating O&M and Capital Costs
Gross margin gains are fighting steep downstream costs. Q2 O&M jumped $11.7M due to the Jim Bridger coal-to-gas conversion and expanding wildfire mitigation. Additionally, depreciation rose $5.2M and net non-operating expenses climbed due to the sheer debt load required to float $1.4B in annual CapEx. If regulatory lag occurs, these fixed costs will brutalize net income.
Macro Pressures: Hydropower Generation Downgrade
Macro weather patterns forced IDACORP to trim the top-end of its 2026 hydropower generation forecast down to 6.5M MWh. With the region facing lower winter snowpack, the company is exposed to elevated purchased power costs on the open market if peak summer cooling demand surges.
Other KPIs
Accelerating significantly. The operating income buffer has expanded substantially compared to the first half of 2025, providing the foundational strength that eliminated the need for heavy tax credit amortization.
Stable. The broader Idaho region continues to pull in steady residential and commercial migration, maintaining a highly predictable >2% baseline growth rate that underpins the 20-year retail sales forecast.
Guidance
Accelerating. The lower end was lifted from $6.25. The new midpoint of $6.375 represents an 8% increase over the $5.90 reported in FY25, showcasing consistent, compounding earnings power.
Reversing. Down from a prior guide of 'Less than $30 million' and massively below the $40.3M used in FY25. This is the clearest forward indicator of robust organic rate base returns.
Decelerating. The top end was slashed by 500,000 MWh due to lagging snowpack dynamics. While reservoirs are adequate, the lack of spring melt presents a tangible power-cost risk heading into Q3.
Stable vs. prior guidance, but represents a material step-up from the $471M recorded in FY25, cementing wildfire mitigation and transition costs into the permanent run-rate.
Key Questions
The End of ADITC Reliance
With zero ADITC usage in Q2 and the full-year guide slashed to under $15M, is it management's expectation that the company will completely graduate from needing this regulatory support mechanism by 2027?
Micron Fab 2 CapEx Upside
Micron's second fab is repeatedly noted as being outside the current load and capital forecasts. What specific contracting or regulatory milestones are required before this massive load is formally embedded into the $7B CapEx guide?
Purchased Power Risk Management
Given the 500k MWh reduction in the top-end hydropower forecast, how is the company managing potential open-market power purchasing exposure if the region experiences extreme Q3 heat?