Diamondback Energy Q1 FY26 earnings call FANG

Diamondback moved from a 'yellow light' to a 'green light' framework, adding 2-3 rigs and a fifth completion crew. Management framed it on macro grounds — two months into what it called the world's largest oil supply disruption in history, with global inventories declining rapidly — and micro grounds, citing the best inventory quality/depth and lowest cost structure in North America. The ramp is executed by drawing down a DUC backlog and bringing back a Halliburton e-fleet simul-frac crew that had been scheduled to go idle for 5-6 months, so five crews now run consistently. The board (13 members) moved quickly after heavy over-communication through the crisis.

Management kept the fixed return-of-capital framework but sought flexibility for cyclical rather than 90-day moves; it raised the base dividend while signaling a slower buyback. With oil prices elevated and, in management's view, not yet capitalized by investors, the bigger use of free cash is rapid debt paydown to convert debt value into equity value in NAV, plus holding cash for a rainy day. Cumulative buybacks stand at 42 million shares for $6 billion at $148/share. M&A is expected to be quiet given deal-making difficulty in volatile markets.

Well performance year-to-date is up versus last year. Post-Endeavor integration, teams shared ideas on completion optimization — perforating strategies, rate design, and sand loadings — driving uplift. On the base production side, workover activity (acid jobs, surfactant jobs) plus machine-learning-driven reduction in downtime (automation/AI in field operations) were a big part of the Q1 beat. Management characterized DUC draws and builds as 'noise' beneath a business executing flawlessly on drilling records across 2-, 3-, and 4-mile laterals and Wolfcamp D development.

Waha pricing is deeply negative; management estimates roughly 2,000-3,000 bbl/d shut in, comparable to an October 2025 maintenance-driven event, though every molecule produced still moves (at a negative price). Financial and physical hedges protect the company, with the mix shifting toward physical as two new pipes arrive in H2 2026. On crude, Diamondback leverages ~300,000 bbl/d to Corpus Christi (EPIC and Gray Oak) and ~100,000 bbl/d to Houston (Wink to Webster), giving water-based pricing exposure plus a small dated-Brent contract. Management wants to replicate this takeaway playbook for gas, including a nearly year-old in-basin power/data-center project.

The incremental 2-3 rigs are almost entirely accelerating Barnett development, largely to get ahead of Barnett obligations in a JV area with a partner where working interest is roughly half-and-half (slightly Diamondback-weighted). Net to Diamondback the ramp is only about 1.5 net rigs, so the top-line activity increase is far less impactful net. The Barnett position is around 200,000 acres; management sees room to grow it via trades and private-equity packages coming to market to block up 3- and 4-mile laterals, with larger per-well production generating more PV today.

Diamondback tested about 5 surfactant wells last year, averaging ~100 bbl/d uplift but ranging from 0 to 400-500 bbl/d per well. This is 'version 1.0'; the team is studying why some wells responded strongly and others not, with the next deployment early this quarter. Management sees the basin on the cusp of technological breakthroughs in increasing recoveries past primary development — a potential 'mega theme' over the next 4-6 years that could extend the basin's life by a decade or two, part of the rationale for holding so much high-oil-in-place acreage.

Management sees private operators adding rigs but at a far smaller scale than the 2022 up-cycle, when private players like Endeavor (2 to 15 rigs), CrownRock (2 to 8) and others drove outsized growth before consolidation. Today's private model is smaller, fast-developed packages — perhaps 20-30 rigs of potential adds, not 100. A Permian rig-count forecast of +25-30 by year-end was given. Service inflation has been minimal so far — largely a capacity question with rig and completion calendars not yet squeezed — though consumables tied directly to commodity prices have seen some pressure.