Antero Resources Corporation Q2 FY2025 earnings call

Management Statement and Operational Highlights

• Capital Efficiency: For the second consecutive year, increased production guidance while decreasing CapEx. Maintenance production target increased 5% from under 3.3 Bcf equivalent per day to over 3.4 Bcf equivalent per day from 2023 to 2025, with maintenance capital requirements declining 26% from $900 million to $663 million. Antero has the lowest maintenance cap per Mcfe at $0.53 per Mcfe, 27% below the peer average.
• Hedges: Added wide natural gas costless collars for 2026, hedged approximately 20% of expected natural gas volumes through 2026, lowering the 2026 free cash flow breakeven to $1.75 per Mcf.
• NGL Fundamentals: Realized C3+ prices averaged $37.92 per barrel in Q2. Expect premiums in the second half of 2025. Export volumes strong, new Gulf Coast export capacity to increase exports and rebalance inventories.
• Natural Gas Demand: Venture Global's Plaquemines LNG facility ramped up, with LNG demand to increase over the next 30 months due to start-ups of facilities like Plaquemines Phase 2, Golden Pass, etc. Appalachian regional power demand announcements rose to almost 5 Bcf, with Antero uniquely positioned to participate in LNG export and regional power demand growth.
• Financial Execution: Second quarter free cash flow was $260 million, with $200 million used to reduce debt and $150 million in share repurchases. Year-to-date, debt reduced by 30% ($400 million) and $150 million of shares repurchased.

Segment Performance

• NGLs: Second quarter realized C3+ cost price averaged $37.92 per barrel. Expected premiums in the second half of 2025 to average $1.50 to $2.50 per barrel, with the fourth quarter anticipated to have the strongest premium. C3+ realizations in Q2 2025 were 59% of WTI, compared to 50% in Q2 2024. Export volumes remained strong, and new Gulf Coast export capacity is expected to increase exports.
• Natural Gas: Venture Global's Plaquemines LNG facility ramped up, leading to higher demand and a premium at the TGP 500 Leg delivery point. LNG demand is expected to increase over the next 30 months, and Appalachian regional power demand announcements increased to nearly 5 Bcf, with Antero advantaged by its resource base, midstream assets, and balance sheet.

Guidance

• Maintenance CapEx: Well costs down 3% year-over-year, expected to continue declining in 2026 with longer laterals and lower declines.
• Hedges: 20% hedged for natural gas volumes through 2026, with upside to $7.
• LNG Demand: Plaquemines Phase 2 and other LNG facilities to increase demand, supporting higher natural gas prices.
• Capital Returns: Continue opportunistic share repurchases and debt reduction based on market conditions, aiming to use free cash flow as opportunities arise.

Risks

• NGL Market Uncertainty: Uncertainty surrounding trade negotiations had a transitory impact on the global NGL market, with shifts in trade flows.
• Regional Pricing Volatility: Regional pricing may remain volatile with sustained periods at a discount to NYMEX due to pipeline constraints and seasonality.
• Appalachian Supply Response: Historically, regional basis tightening has been short-lived due to Appalachian supply and pipeline takeaway constraints, but potential change with fewer players and less core inventory.

Question and Answer

Q: Arun Jayaram asks Dave Cannelongo about the implications of Gulf Coast LPG export capacity on Mont Belvieu pricing.

A: Dave Cannelongo responds on export capacity build-out and its impact on benchmark pricing.

Q: John Freeman asks about the direction of maintenance CapEx in 2026.

A: Michael Kennedy talks about well costs declining and expected further decline in 2026 due to longer laterals and lower declines.

Q: Doug Leggate asks about the sustaining capital mix and future improvement.

A: Michael Kennedy discusses maintenance capital continuing to improve because of lateral length and lower declines.

Q: Greta Drefke asks about capital returns and the debt level for ramping up.

A: Michael Kennedy talks about acting opportunistically based on market conditions and stock valuation.

Q: David Deckelbaum asks about return on capital thoughts.

A: Michael Kennedy says they consider the implied return on paying down debt vs buying back shares based on cash flow outlook and valuation.

Q: Kevin MacCurdy asks about production mix change.

A: Michael Kennedy talks about lean gas pads brought on and expected mix reversal in Q4.

Q: Kevin MacCurdy follows up on collars and the macro view.

A: Michael Kennedy discusses skew in the gas market and benefits of hedging.

Q: Leo Mariani asks about in-basin demand projects.

A: Michael Kennedy talks about Antero's unique position, integration, and requirements for accretive deals.

Q: Leo Mariani follows up on in-basin demand discussions.

A: Michael Kennedy says they have an internal team but no timing on announcements.

Q: Leo Mariani follows up on shareholder returns.

A: Michael Kennedy says they continue share buyback based on market conditions.

Q: Phillip Jungwirth asks about the TGP 500 Leg premium ceiling.

A: Justin Fowler talks about potential further upward movement due to LNG demand and global contracts.

Q: Phillip Jungwirth asks about the Appalachian differential.

A: Michael Kennedy says it could be different with fewer players but Antero is well-positioned.

Q: Betty Jiang asks about NYMEX-linked power supply deals.

A: Michael Kennedy talks about Antero's leverage due to being investment-grade and integrated.

Q: Betty Jiang follows up on West Virginia power opportunities.

A: Michael Kennedy mentions West Virginia's Microgrid Bill and Antero's favorable position.