BKV Corporation

BKV reported record adjusted EBITDAX of $142 million and record adjusted net income of $51 million, more than twice first quarter 2026 despite lower natural gas prices. Temple generated over 2,200 gigawatt hours, up 16% year over year, at a 70% capacity factor; on a hedged basis, power prices averaged $42 per megawatt hour and spark spreads averaged $22 per megawatt hour, driving gross power adjusted EBITDA of $36 million. Total capital expenditures were $198 million, adjusted free cash flow was $40 million, net debt was $1.1 billion, net leverage was 1.8x, and total liquidity was $840 million. Upstream production guidance was raised to a midpoint of 950 million cubic feet equivalent per day, implying 3% to 4% year-over-year production growth. Full-year strategic power CapEx was increased to $400 million to $475 million, while 2026 upstream gas differentials were expected to be slightly wider and ethane rejection was planned for the remainder of the year.

Chris Kalnin framed the quarter as evidence that BKV’s integrated gas-power-carbon capture model is working and said the company delivered across every business line. He emphasized the Temple and Jack County power builds, the company’s engagement with ERCOT and other stakeholders, and the view that BKV’s “one-stop shop” offering is differentiated and repeatable. His tone was upbeat and confident, especially on the outlook for power demand, Temple commercialization, and the CCUS platform.

David Tameron highlighted that the quarter was the first to fully reflect the “sustainable earnings power” of the consolidated closed-loop business. He cited record adjusted EBITDAX of $142 million, record adjusted net income of $51 million, $198 million of total CapEx, and $40 million of adjusted free cash flow, while noting power spending rose because BKV accelerated long-lead equipment purchases to preserve schedule certainty. He also said BKV ended with $1.1 billion of net debt, 1.8x leverage, and $840 million of liquidity, and that the company expects to fund growth through liquidity, free cash flow, equipment financing, power JV refinancing, and project-level financing.

Analysts focused on Jack County commercialization, interconnection/batching risk, financing for the larger power buildout, the potential sale of Northeast Pennsylvania, and the meaning of the 400 MW air permits at Temple. Management said Jack County is being designed very similarly to Temple, with behind-the-meter generation and grid connectivity preferred for reliability and the ability to sell excess power back to the grid. On financing, management said the higher power CapEx is not a challenge, pointed to $170 million of cash and $840 million of liquidity, and outlined near-term equipment financing and a power refi, plus future project finance once PPAs are signed. On Temple permits, management said the 400 MW permit preserves optionality rather than implying an immediate 400 MW Phase 1 build, and on Northeast Pennsylvania they remain open to monetization only if the offer is compelling.