Diamondback Energy, Inc. Q3 FY2026 earnings call

• Taxation: Management acknowledges paying a higher overall tax rate compared to peers but asserts they are paying their fair share.
• Gas Market Dynamics: Higher Waha gas prices are expected to provide cash flow benefits. The company has significant gas inventory in its backlog that has not yet been drilled due to previous price conditions.
• Operational Efficiency (LOE): Lower-than-guided Loss of Equity (LOE) costs were a key driver of the EBITDA beat. This is attributed to effective cost control despite an inflationary environment.
• AI and Technology: AI optimization of artificial lifts (manpower and compression) is delivering productivity uplifts and minimizing downtime during storms. Approximately 1,000 plunger lift wells are being brought online via this technology within months.
• Development Cadence: The normalized development program targets running 19-20 rigs and five fracturing crews consistently. Output volume per quarter may vary (120-140 thousand barrels) based on well timing, but the program aims for organic growth.
• Barnett Basin Performance: The Barnett region is showing superior results relative to peers due to targeted geology, specifically reservoir energy and thickness. It currently represents about 20% of drilling activity.
• Enhanced Oil Recovery (EOR): Early-stage EOR/chemical projects are underway with a capital allocation of $50-$100 million against a >$4 billion budget. Success will determine future capital intensity.

The provided transcript does not contain specific financial data, revenue figures, or segment breakdowns for Diamondback Energy's product segments. It focuses exclusively on operational commentary and Q&A discussions.

• 2027 Capital Expenditures: Management indicated that if the company runs five frack crews through 2027, CapEx might exceed the current high-end guidance of $1.05 billion quarterly, particularly if oil prices remain near $100.
• Production Growth: The company is targeting a level-loaded program designed to generate organic growth, though specific volume targets for 2027 were not explicitly quantified in the excerpt.
• Gas Production Potential: While no specific forward guidance was given for gas volumes, management noted that gas production is currently occurring 'without trying' and could potentially grow significantly (10-15% YoY) if price signals warrant dedicated drilling, subject to value chain control.

• Value Chain Control: Expanding into gas-specific drilling requires control over processing and transportation costs, which currently limits the ability to drill purely for gas volumes.
• EOR Uncertainty: Enhanced Oil Recovery technologies are in early stages; their rate of return is unproven at scale, and capital allocation depends on future performance metrics.
• Geological Variability: Productivity in new areas like the Barnett is highly dependent on specific geological factors (energy/thickness), requiring precise targeting to replicate success.

Q: Analyst asked if higher gas prices would unlock undrilled inventory and drive operational uplifts beyond cash flow.

A: CEO confirmed significant gas inventory exists in the queue, previously undriven by lower prices. He noted that basin-wide higher gas cuts will occur as these zones are accessed, representing a latent opportunity rather than an immediate operational change.

Q: Analyst inquired about the drivers behind the EBITDA beat, specifically questioning whether General & Administrative (G&A) or other operational expenses contributed more than Loss of Equity (LOE).

A: CEO clarified that the primary focus is on controllable LOE reductions. Regarding Gas Processing & Transportation (GP&T), he explained that performance is a mix of gas realizations and GP&T costs, implying the beat was largely driven by favorable realization mixes and controlled LOE rather than G&A efficiencies.

Q: Analyst sought details on the timeline and productivity impact of AI-optimized artificial lifts, specifically regarding plunger lift wells.

A: CEO highlighted that AI autonomous controls significantly minimize downtime during adverse weather, boosting productivity. He stated that bringing the remaining 1,000 plunger lift wells online using this technology is a matter of months, not quarters.

Q: Analyst asked about the maturity and capital allocation strategy for Enhanced Oil Recovery (EOR) and chemical injection technologies.

A: CEO described the current efforts as 'the first pitch,' comparing them to early Wolf Camp developments. He outlined a modest initial investment of $50-$100 million, emphasizing that further capital will be allocated only if the technology proves successful and improves rates of return.

Q: Analyst questioned the potential for doubling gas volumes year-over-year if the company pivoted to gas-focused drilling, given current macro trends.

A: CEO cautioned that while natural gas volumes are growing passively, active gas drilling requires controlling the entire value chain (processing, transport, sales). He suggested that without this vertical integration, the company remains far from drilling specifically for gas, viewing it as a long-term strategic shift rather than an immediate volume lever.