Vital Energy, Inc.

Second-quarter consolidated EBITDAX was $338 million, and adjusted free cash flow was $36 million. Capital spending was $257 million, above the high end of guidance, due to $11 million of accelerated third-quarter activity and $13 million of drilling cost overruns. Total production and oil volumes were within guidance even after weather-related impacts and temporary curtailments, which reduced daily production by 780 boe/d, including about 500 bbl/d of oil. Management said it remains on track to meet the midpoint of its $875 million capital investment guidance for 2025. For the second half, the company expects 38 wells to turn in line, all producing by October, and is targeting about $25 million of net debt reduction in Q3 and around $185 million in total for the remainder of the year. It also noted it swapped roughly 95% of expected second-half oil production at an average price of $69 per barrel, hedged about 85% of expected natural gas production, and 75% of ethane and propane volumes.

Jason Pigott framed the quarter as evidence that Vital is shifting from acquisition-driven growth to optimization and cash generation. He emphasized sustainable cost reductions, including lower LOE, lower G&A, and new well designs like J-Hooks that improve inventory and reduce breakevens. His tone was constructive and confident, with repeated focus on second-half free cash flow, debt reduction, and long-term shareholder value.

Bryan Lemmerman focused on financial discipline, saying the company expects to continue paying down debt in 2026 even though formal guidance has not been issued. He pointed to the hedge book as a key support for cash flow, noting a corporate breakeven below $55 per barrel for 2026 with current hedges, and suggested adding third-quarter 2026 hedges could push that into the low $50s. He did not provide additional quarter-by-quarter financial detail beyond reinforcing the debt-paydown outlook.

Analysts pressed management on 2026 production cadence, capital efficiency, and whether the current level of noncore asset sales is repeatable. Management said Q2 acceleration was mainly to de-risk timing rather than pull forward growth, that 3 of the 38 remaining wells account for 33 wells’ worth of the program, and that fourth-quarter volumes should be the high point before easing in early 2026 due to timing. On asset sales, Jason Pigott said the company is opportunistic rather than setting a fixed target, selling noncore assets when pricing is attractive to help accelerate debt reduction. Questions on 2026 leverage and hedging drew the response that debt should keep trending down and that the company may add more hedges, lowering breakeven further.