CENTERPOINT ENERGY INC Q3 FY2026 earnings call

• Strong Q3 Execution: Reported non-GAAP EPS of $0.53, bringing year-to-date performance to nearly 80% of the original full-year guidance midpoint. This strong execution supports raising the 2026 non-GAAP EPS guidance.
• Accelerating Houston Growth: Customer demand in Greater Houston is accelerating, with approximately 14 gigawatts (GW) of eligible load submitted for ERCOT’s Batch Zero process. Management remains confident in 10 GW of baseload demand, expecting at least 14 GW to be energized by end-of-decade.
• Capital Plan Increase: Announced a $4 billion increase to the 10-year capital investment plan (totaling $70.7 billion) and accelerated $1.5 billion of projects into the first five years (through 2030). This drives an enterprise rate-based CAGR of >14% through 2030.
• Transmission Study Results: Identified >$5.5 billion in transmission projects (brownfield-heavy, ~85%) to address import capacity, system stability, and intra-regional needs. These investments replenish capacity consumed by new industrial loads.
• Long-Term Opportunity: Identified at least $10 billion in additional investment opportunities through 2035, including further transmission infrastructure, resiliency initiatives, and large-load opportunities in Indiana.
• Portfolio Optimization: Completed the sale of the Ohio Gas LDC business in October 2026 for ~$1.4 billion, reflecting a focus on efficient capital allocation. Marketing temporary generation units for sublease or sale.
• Reliability & Affordability: Houston Electric has seen a ~40% improvement in reliability. The growth model aims to generate $5 billion in customer savings over 10 years via competitive speed-to-market advantages.

The transcript does not provide a breakdown of financial performance by specific product segment (e.g., Electric vs. Gas) in terms of absolute revenue contribution percentages or distinct profit margins for each division. The company reports consolidated GAAP EPS of $0.50 and non-GAAP EPS of $0.53 for the third quarter of 2026. Financial results are driven primarily by the Houston Electric Service territory, which benefits from updated interim rates effective June 2026, contributing 9 cents to earnings favorability. Other drivers include weather/usage (3 cents favorable, largely due to a one-time deferred tax remeasurement) offset by higher financing costs ($0.04 unfavorable). The company highlights that nearly all incremental capital expenditures are recoverable through capital tracker mechanisms, ensuring efficient funding across its service territories.

• 2026 Non-GAAP EPS: Raised from $1.89–$1.91 to $1.90–$1.92. Midpoint represents ~9% growth over 2025 delivered results.
• 2027 Non-GAAP EPS: Provided guidance of $2.07–$2.09, representing 9% growth at the midpoint from the increased 2026 guidance.
• Long-Term Outlook: Extended expectation for non-GAAP EPS growth at the mid-to-high end of the 7%–9% annual range through 2030 and annually through 2035.
• Equity Financing: Increased remaining 10-year equity financing guide by $1.6 billion to $4.5 billion to fund 40% of the $4 billion capital plan increase, well below the historical 47% rule of thumb.
• Rate-Based Growth: Expects enterprise rate-based CAGR of more than 14% through 2030 driven by the accelerated capital deployment.

• Execution Risk: Significant capital deployment ($4B increase + $1.5B acceleration) requires efficient execution to maintain credit metrics and avoid regulatory lag impacts.
• Regulatory Lag: While capital trackers mitigate cash lag, there is potential strain on balance sheets if interim recovery of long-cycle transmission investments is not secured, particularly given lower equity ratios in Texas.
• Interest Rate Environment: Higher interest rates pose a headwind for refinancing and borrowing costs, though mitigated by low near-term maturities (~$300M in 2027) and credit upgrades.
• ERCOT Audit Uncertainty: Approximately 2 GW of studied load withdrew during the ERCOT audit process; while management is confident in the remaining 10 GW, the final determination depends on state audit outcomes.
• Operational Disruptions: Although ~85% of new transmission work is brownfield, future greenfield 765 kV submissions may face landowner rights challenges and community disruption risks.

Q: Char Perez asked about the delta between the 14% rate-based growth and EPS growth, questioning if equity dilution explains it and if portfolio sales could fund future CapEx.

A: Jason Wells clarified that while equity dilution exists, the company historically converts rate-based growth into EPS growth with only a ~200 bps delta. He emphasized that the primary driver for the gap is conservative planning to ensure consistent delivery rather than hidden financial factors. Regarding portfolio optimization, he noted that while dis-synergies can be addressed, the main focus is efficiently raising equity to support explosive Houston growth, with portfolio sales being one of several tools considered.

Q: Julian Dumoulin-Smith asked about levers against the $1.6B equity need, specifically regarding temporary generation units, demand charges, and asset sales.

A: CFO Chris Foster outlined four levers not reflected in the current plan: 1) Cash flow from subleasing or proceeds from selling temporary generation units returning in Q1 2027; 2) Demand charges (~$6M/GW/year) from Batch One customers exceeding Batch Zero levels; 3) Further portfolio optimization akin to the Ohio sale; and 4) Regulatory improvements to reduce cash lag. He confirmed these alternatives could reduce the required equity issuance.

Q: Steve Fleishman asked if the new transmission projects were lower voltage and why some load dropped from Batch Zero to studied status.

A: Jason Wells confirmed the announced transmission projects are lower voltage (345/138 kV), with ~85% being brownfield to minimize disruption. He explained that the 2 GW drop in studied load occurred because those customers withdrew during the state audit process as they finalized details. However, management remains confident in the 10 GW baseload commitment and sees distribution-level growth and early Batch One trends offsetting these losses.

Q: Julian Dumoulin-Smith asked about the trend of data centers and large loads manifesting at the distribution level and its impact on margins.

A: Jason Wells highlighted a fundamental shift where commercial warehouse leasing in Houston is up 30%, driving second-order economic activity. He noted significant interest in distributed, modular distribution-level data centers for AI inference under 75 MW. This ecosystem growth accelerates distribution-level demand, which offers different earning power dynamics compared to transmission, reinforcing the need for capacity expansion at both levels.

Q: Richard Sunderland asked about regulatory efforts to reduce lag, specifically regarding Minnesota and Texas legislative changes.

A: Jason Wells detailed that Minnesota will file a three-year forward-looking rate case, allowing annual revenue adjustments and eliminating flat-revenue years common in shorter cycles. In Texas, he advocated for revisiting interim recovery mechanisms for long-cycle transmission investments to protect balance sheet health amid high growth. He emphasized proactive stakeholder engagement to balance landowner rights with the need for continued economic development.