Talen Energy Corporation (TLN) Earnings

Management highlights

- Core Strategy: Management maintains its flywheel strategy centered on owning low-cost baseload generation assets in advantaged locations (PPL zone, AEP Ohio), securing long-term contracts, and supplementing existing assets with a development pipeline of powered land and new capacity. The PPL zone has excess generation and transmission capacity that positions it well to accommodate growing data center load, with multiple large data center projects including an AWS campus already in development. The strategy blends existing baseload energy with new capacity additions in front-of-the-meter grid-connected solutions, which management views as more reliable, durable, and lower-cost than behind-the-meter alternatives. - Operational Performance: Safety is the top priority; the company recorded a recordable incident rate of 0.27, below the industry average, during the spring outage season and integration of new assets. The fleet achieved an equivalent forced outage factor of 3.9%, generated ~30 terawatt hours of electricity, and reached a 51% fleet-wide capacity factor, 14 percentage points higher than the prior year, driven by newly acquired assets and higher run times for intermediate/peaking assets supporting grid demand. 70% of the 10 highest peak load days in modern PJM history have occurred in the last 15 months, with 5 in July 2026 alone, driving higher generation output. - Market Fundamentals: PJM demand is forecast to grow over 17% through 2030, and total U.S. power demand is projected to grow over 20% over the same period, validating management's thesis of significant ongoing load growth. 2028 PPL spark spreads are up 28% and WestHub spark spreads are up 27% compared to July 2025 investor day pricing, as forward markets have finally begun to reflect observed demand tightness. The PPL zone basis discount to PJM West Sub has widened from a historical ~$9/MWh to ~$20/MWh due to temporary transmission upgrade outages between PPL and southern load pockets; management expects the basis to narrow as upgrades are completed and in-zone load grows, with every $1 basis improvement equating to ~$1 per share higher adjusted free cash flow. - Capital Allocation: The company is committed to returning 70% of adjusted free cash flow to shareholders via share repurchases. It repurchased 550,000 shares in Q2 2026, and has over $1.9 billion in liquidity providing capital allocation flexibility. Management targets a net leverage ratio of 3.5x, and any excess capital after shareholder returns will be directed to the highest value use, including additional buybacks or selective accretive growth investments. - Contracted Portfolio Evolution: As the AWS campus contract ramps to full build-out between 2028 and 2030, long-term contracted gross margin will increase from 10% to 35% of total margin, making AWS the largest revenue stream and de-risking exposure to merchant markets post-2030. If the company executes an additional ~2 gigawatts of long-term contracts by 2030, long-term contracted margin could reach 60% of total, shifting the business to a more infrastructure-like cash flow profile.

Guidance

- Following the closing of the Cornerstone acquisition, management raised 2026 full-year guidance: adjusted EBITDA guidance is now $2.025 billion to $2.225 billion, and adjusted free cash flow guidance is $1.2 billion to $1.35 billion. The guidance includes acquisition impacts, updated market conditions, and an offset from the pending sale of the company's Keystone interest. - Management maintained the 2027 base case adjusted free cash flow per share outlook at $34 and raised the 2028 base case adjusted free cash flow per share outlook to $40 (from $36 previously), assuming a flat share count of 47.9 million as of end-Q2 2026. When accounting for planned share repurchases, management forecasts 2027 adjusted free cash flow of ~$37 per share and 2028 adjusted free cash flow of ~$48 per share, representing a over 14% free cash flow yield at current share prices. - Between the second half of 2026 and the end of 2028, management expects to generate ~$4 billion of adjusted free cash flow, with at least 70% ($2.8 billion) to be returned to shareholders via share buybacks. This equals almost 20% of the company's current market capitalization. - Multiple upside levers could push 2028 adjusted free cash flow per share above $50, including creative M&A, accelerated execution of the 2 gigawatt PPA pipeline, new data center PPAs, further expanding spark spreads, and normalization of the PPL zonal basis. - Going forward, the company will return to its standard annual guidance practice: full guidance for the upcoming year, plus outlooks for the two subsequent years, will be provided each fall during the Q3 earnings call. Extraordinary mid-year guidance updates will only be provided in the event of material business changes like large M&A.

Segment performance

Talon Energy does not break out performance into distinct product segments in this call. All financial results reflect the company's combined portfolio of natural gas-fired baseload generation capacity, development pipeline of powered land for data center solutions, and new capacity projects (batteries, peaker plants, upgrades). For Q2 2026, the company reported $374 million adjusted EBITDA and $212 million adjusted free cash flow. Year-to-date through Q2 2026, adjusted EBITDA was $847 million and adjusted free cash flow was $562 million, with a free cash flow conversion rate in the mid-60% range. The company added 2.5 gigawatts of efficient natural gas generation via the closed Cornerstone (Waterford, Darby, Lawrenceburg plants) acquisition in June 2026, ahead of peak summer demand.

Risks & headwinds

- The current widened PPL zone basis discount, driven by temporary transmission upgrade outages, negatively impacts near-term pricing and cash flow, though management expects this to reverse over time. Basis hedging opportunities are limited due to low liquidity in PPL zone trading, making it difficult to fully monetize or offset the current basis mismatch. - PJM regulatory and market rule changes (including the RBP capacity framework and IRAS/Connect and Manage rules) are still being finalized, creating uncertainty around market structure, participation requirements, and the viability of existing and new development projects. There are open questions around jurisdictional, discriminatory, and implementation risks for the proposed IRAS/Connect and Manage rules. - Long-term capacity pricing post-2030 is supported by early bilateral bids but remains thinly traded, creating uncertainty around future market valuation of generation capacity. - New long-term data center contracting depends on customer capital allocation and planning timelines, which can be slower than expected, and may be impacted by political and regulatory noise around data center development. Execution of new capacity projects depends on clearing required hurdle rates for returns, which may not be met depending on final market and cost conditions.

Analyst Q&A

• Q: What is management's view on PJM's recent FERC filing for the RBP capacity framework, and do you plan to participate? /

  A: The filing was largely in line with expectations, and management is broadly supportive of the framework overall. Key positive components include protection for existing contracts and the 555 average soft cap structure that allows more flexible clearing. The 695-page filing is still under review, and management is evaluating potential changes to improve the framework before the September 29 FERC finalization deadline (required ahead of the December auction). Management plans to participate and believes several of its developed projects are viable candidates, but final participation will depend on how the process evolves.

• Q: With current forward PJM curves in flux, how is management adjusting hedging strategy to preserve upside potential? /

  A: Management has consistently maintained a hedging approach that uses instruments to fence in outcomes while retaining exposure to further upside. Hedge coverage for 2028 increased 5% quarter over quarter to 30%, with lower coverage for longer-dated periods. Management intentionally acquired more baseload generation because it believed energy and capacity were underpriced and would become more valuable, a thesis that has been validated as forwards have now started to reflect market tightness.

• Q: What are the gating factors for new long-term data center contracting, and how does the $555 RBP auction cap impact what types of projects you bid? /

  A: There is no single dominant gating factor; contracting timelines depend primarily on customer capital allocation and planning cycles, with demand for 2028-2029 on-stream projects already strong. The 555 cap is a floating average that allows individual offers above the cap, so it does not inherently shift bidding toward batteries over other resources. Upgrades to existing assets, batteries, and peakers are all likely to clear the stack depending on project economics, and management views RBP as a positive first step to solve near-term capacity needs by procuring new generation.

• Q: How does management prioritize M&A versus other capital allocation options like share repurchases in the current landscape? /

  A: M&A has been a core part of the company's growth strategy, and management continues to evaluate accretive opportunities that add free cash flow per share. However, at current share prices, the free cash flow yield on share repurchases sets a high hurdle for M&A; management will only pursue transactions that clear this hurdle. The company maintains flexibility to use equity or debt to finance attractive deals, but always prioritizes growing free cash flow per share for shareholders.