XCEL ENERGY INC Q3 FY2026 earnings call

• Infrastructure Investment & Growth: Xcel Energy is executing a $70 billion five-year capital investment plan (2027-2031) to modernize grid infrastructure, expand renewable generation (>9 GW), add natural gas-fired generation (>3 GW), and deploy energy storage (>2 GW). This includes 2,400 new high-voltage transmission line miles.
• Data Center Demand: The company anticipates contracting an additional 1 GW of data center load by end of 2026 and another 3 GW by end of 2027. These projects are largely funded through incremental opportunities outside the base $70B plan, supported by large-load tariffs that ensure new customers do not subsidize existing ones.
• Regulatory Progress: Constructive decisions or settlements have been reached across 90% of the rate base. In Minnesota, a proposed rate stabilization plan aims to keep customer base rates flat in 2027-2028 while supporting investments.
• Operational Excellence & Safety: The company maintains strong reliability metrics, scoring in the first quartile for customer satisfaction (J.D. Power). Operational highlights include placing the 335-MW Arroyo II solar facility into service in Colorado and securing a $250 million DOE SPARC grant for interconnection modernization.
• Affordability Focus: Residential electric and natural gas bills remain significantly below national averages (29% and 11% lower, respectively). The 'Steel for Fuel' program is projected to save customers ~$18 billion by 2031 through tax credits and avoided fuel costs.

The transcript does not provide a detailed breakdown of financial performance by specific product segment (e.g., Retail Electric vs. Wholesale) with absolute revenue figures or contribution percentages. Management reports consolidated third-quarter ongoing earnings of $1.52 per share, up from $1.24 in the prior year period. Key drivers included $0.32 EPS growth from electric revenues (due to non-fuel riders, regulatory outcomes, sales growth, and favorable weather), $0.11 EPS growth from AFV/DC, and offsetting decreases from higher interest expense ($0.13) and common equity financing ($0.10). Weather-adjusted electric sales increased 2.5% year-to-date.

• 2026 Ongoing EPS: Narrowed guidance range to $4.10 - $4.16 per share.
• 2027 Ongoing EPS: Initiated guidance range of $4.48 - $4.62 per share.
• Long-Term EPS Growth: Extended expectation of average 9%+ EPS growth through 2031, with average 10%+ EPS growth expected from 2027 to 2030.
• Dividend Growth: Maintaining objective of 4% - 6% annual dividend growth, targeting the low end of the range.
• Capital Plan: Updated $70 billion five-year investment plan anchored in serving existing demand, grid resilience, and clean energy transition, with >$10 billion in incremental opportunities driven by RFPs and data centers.

• Interest Rates & Financing Costs: Higher interest expenses and common equity financing needs were noted as headwinds to current quarter earnings, reflecting the cost of funding infrastructure investments while maintaining balance sheet discipline.
• Regulatory Lag: While progress is strong, regulatory timing impacts cash flow and rate recovery; however, management notes that over 40% of the 2027-2031 equity need is already contracted, providing flexibility.
• Project Execution & Supply Chain: Reliance on strategic partnerships with EPCs and OEMs to deliver complex projects on budget and on time; any delays could impact the pace of capacity additions for data centers and renewables.
• Weather & Climate Risks: Increased frequency of extreme weather events (heatwaves, wildfires) requires continuous investment in vegetation management and wildfire mitigation, impacting O&M expenses.

Q: Nicholas Campanella asked about the shaping of EPS growth relative to rate-based growth, noting a potential deviation from the historical 200-250 bps delta between the two metrics in the near-term plan. / A: Brian Van Abel explained that while the rule of thumb holds over the full six-year period, point-to-point sensitivity exists due to front-loaded equity financings. He clarified that 2026-2030 shows ~14% rate-based growth against 10%+ EPS growth, slightly outside the typical delta, but the longer-term view aligns with expectations, ensuring balanced balance sheet maintenance.

Q: Carly Davenport sought clarity on the confidence level for signing 1 GW of data center load by year-end and the trajectory toward the 3 GW target for 2027, specifically regarding development partnerships. / A: Brian Van Abel stated they are in active negotiations for a large counterparty to hit the 1 GW target. He highlighted that the Upper Midwest and SPS regions offer the most immediate opportunities, while Colorado is later-cycle due to tariff hearings. He emphasized expanding partnerships beyond NextEra to manage the 25 GW pipeline of generation needed to serve these loads affordably.

Q: Jeremy Tonnet questioned the productivity of CapEx in Colorado given industry scrutiny on affordability and asked about the strategic rationale and timeline for the small asset sale in Michigan. / A: Bob Frenzel and Brian Van Abel affirmed all CapEx is productive, citing EV adoption and wildfire mitigation as cost-enhancing. Regarding Michigan, Van Abel noted it represents only 0.2% of the rate base, involves selling to strategic local buyers, and is expected to close by late 2027, with proceeds integrated into the broader financial plan.

Q: Richard Sunderland asked how the upside CapEx from data centers and RFPs might impact the 11% CAGR guidance and what policy priorities would shape the next 12 months. / A: Van Abel explained that every billion dollars of CapEx adds 15-20 bps to the rate-based CAGR, suggesting upside potential as data center projects bring significant upstream generation investment. Frenzel outlined policy priorities including bipartisan siting/permitting reform at federal and state levels, wildfire mitigation legislation, and timely cost recovery mechanisms, particularly in Texas and New Mexico.

Q: Steve D'Ambrisi asked if the Minnesota rate stability plan using Clean Energy Tax Credits could be replicated elsewhere and how PSCO's slower growth outlook compares to other regions. / A: Van Abel described the Minnesota ITC utilization as a creative tool for affordability that could be explored in other jurisdictions. Frenzel attributed PSCO's lower growth profile to conservative planning and pending large-load tariffs, contrasting it with the robust, diversified growth in SPS (oil/gas electrification and data centers) and the Upper Midwest, which provides geographic diversification against regional weather or economic risks.