Expand Energy Corporation 3Q 2026 Earnings Call - SOUTHWESTERN ENERGY CO

Explicit Guidance:

• Q4 2026 Marketing Profit: Expected combined marketing and commercial profits (including Twin Eagle) to add $80 million in EBITDA, or $0.12 per MCFE, during a low-volatility environment.
• Run-Rate Targets (Marketing & Commercial):
  • 2028: Line of sight to $500 million in total marketing and commercial EBITDA, translating to $0.20 per MCFE.
  • Post-2028 (2030+): Potential to reach $750 million in additional EBITDA (approx. $0.30 per MCFE) upon capturing LNG and other structural demand opportunities.
  • Breakeven Reduction: Target $250–$260 per MCFE cash breakeven by 2028, driven by commercial synergies and dividends; interim target of $260 per MCFE expected in 2028.
• Capital Allocation & Spending:
  • 2026 Capex: Maintained at $3 billion annually ($750 million/quarter).
  • 2027 Capex Outlook: Anticipating low-to-mid single-digit inflation (driven by rate counts, OCTG, and pressure pumping); 50% reduction in diesel usage anticipated due to e-fleet adoption.
  • Leasing: $250 million spent in 2026; similar run rate expected for 2027, with opportunistic land acquisitions continuing.
  • Share Repurchases: Continuation expected in Q4 2026 and early 2027 to support value creation, balanced against balance sheet deleveraging.
• Production: Guidance for Q4 2026 production set at 7.4–7.6 BCFE per day, reflecting flexibility to manage curtailments and turn-in lines based on price.
• Hedging: 55% hedged for all of 2027 at a weighted average price of $3.65.

Business-Segment Outlook:

• Integrated Gas Platform: Transition from pure upstream to an integrated model (upstream + marketing + LNG) aims to capture incremental margin along the value chain.
• Twin Eagle Integration: Synergies and operational integration are expected to materialize fully by 2028, with early financial benefits visible immediately post-close (Sept 16).
• Commercial Customer Base: Leveraging Twin Eagle's 1,000+ customer relationships across C&I, power, and LNG sectors; focus on securing longer-dated contracts and higher volumes.
• Production Flexibility: Maintaining ability to utilize curtailments, deferred drilling, and flexible turn-in lines to align supply with price cycles; ~13 BCFE/day of new incremental demand expected by end of 2028.
• Western Haynesville: Appraisal status continues; breakeven estimated at > $4.00 currently; plan to drill 2 wells in 2027 as a "call option" for future demand; not part of near-term base inventory due to depth and cost.
• Appalachia (Southwest): Achieved 20% improvement in footage per day and 10% improvement in cost per foot (2025–2026); expecting 2–3% well productivity growth year-over-year in 2027 via optimized completion designs and internal sand supply.
• LNG Strategy: Building a portfolio of liquefaction and offtake to tie domestic production to international pricing (premium to Henry Hub); Delphin agreement for 1.15 million tons of offtake starting 2031–2032 serves as a foundation for expansion.

Market and Competitive Outlook:

• Demand Drivers: Structural demand increase anticipated driven by LNG, data centers (nationwide, including Midwest, Texas, Louisiana), and industrial projects.
• Supply Dynamics: Market currently well-supplied (LNG flows at record highs, Permian egress growth), suppressing the 2027 price curve; however, demand is expected to outpace supply growth by 2028–2030, leading to higher prices.
• Infrastructure: New Permian pipelines (Black Bend, Trident, Mustang) expected to start up in 12–18 months, alleviating Houston bottlenecks but not sufficient to meet demand through 2028.
• Competitive Advantage: Leveraging "coast-to-coast" connectivity (via Twin Eagle) to access data centers and industrial customers outside core basins, offering supply security to premium customers willing to pay more.
• Pricing Environment: Low prices in Q4 2026 and 2027 viewed as temporary; market expected to transition to higher prices as demand growth materializes in the 2028–2030 window.

Macro / Industry Outlook:

• 2027 Outlook: Viewed as a "transition year" with weak fundamentals and potential headwinds from Super El Niño weather patterns and Permian supply trends; company remains flexible to manage production accordingly.
• Long-Term Fundamentals: Highly constructive view on natural gas through 2030, driven by the 13 BCFE/day supply-demand gap anticipated by year-end 2028.
• Inflation: Anticipated inflation shift from diesel (major cost in 2026) to rate counts and OCTG in 2027, though mitigated by efficiency gains and fleet electrification.
• Regulatory/Environmental: No specific regulatory changes mentioned, but company emphasizes alignment of production with price cycles to maintain resilience.

Strategic Initiatives:

• Twin Eagle Acquisition: Closed September 16, 2026; teams integrated into single office to accelerate synergy realization; viewed as critical for adding commercial capabilities and customer relationships.
• Leadership Change: Danny Brown appointed permanent CEO; selection focused on upstream expertise, capital allocation discipline, and public CEO experience to sustain momentum.
• M&A Stance: Open to disciplined, inorganic opportunities (both upstream and downstream) that offer significant synergies and risk-adjusted full-cycle value; no immediate plans to acquire following recent peer deals (e.g., EQT/Range).
• Operational Efficiency: Continued focus on AI implementation for value unlocking; doubling down on continuous improvement in drilling/completion efficiency (e.g., internal sand supply).
• Organic Growth: Continued robust ground game for lease acquisitions; expecting to add high-productivity inventory (e.g., Bradford County, PA) at low entry costs.

Risks and Headwinds to Outlook:

• 2027 Price Suppression: Risks from excess supply (Permian egress, LNG flows) and weather-related production fluctuations (Super El Niño) may delay the anticipated price recovery.
• Inflationary Pressures: Potential increases in OCTG, pressure pumping services, and rate counts could impact 2027 capital efficiency despite e-fleet benefits.
• Storage Levels: Elevated storage levels heading into spring/summer 2027 could create market overhang.
• Execution Risk: Integration of Twin Eagle and realization of the $750 million marketing EBITDA run-rate depend on successful deal flow and customer contract execution; timing remains uncertain.
• Western Haynesville: High development costs and technical complexity (deep, over-pressured reservoir) mean this asset is not yet a core production driver and requires >$4 gas to compete.

Management Tone on the Future:

• Confidence Level: Extremely high; leadership describes optimism as "stronger than ever" and believes the company is "well-positioned" to capture value as prices rise.
• Strategic Clarity: Emphasis on the "foundation is set" narrative, shifting focus to execution and leveraging the integrated platform.
• Resilience: Highlighting the resiliency of free cash flow margins ($1.00+ FCF/MCFE historically) and the ability to generate profits even in low-price environments via the commercial arm.
• Discipline: Reiteration of a "disciplined approach to value creation" and "patience" in capital allocation; balancing debt reduction with opportunistic buybacks.

Miscellaneous:

• Share Count: Net debt at $4.7 billion with leverage of 0.8x (as of Q3 2026); focus on deleveraging post-Twin Eagle acquisition while maintaining buyback options.
• Operational Metrics: Produced approximately 7.5 BCFE/day in Q3 2026; extended drilling inventory via organic leasing.
• Hedging Performance: Hedge program improved realized prices by $0.46 per MCFE and generated over $300 million in value during Q3 2026 relative to weak strips.