Sam Margolin

Acknowledged the trend but explicitly declined to detail specific strategic projects.

Direct on project type and discipline, though no dollar figure for go-forward strategic spend beyond the historical range.

Randy noted that during 2025 differentials were so narrow that sweet vs sour was indifferent through Q2-Q3, but current levels firmly favor maximizing heavy and medium sour purchases to fill refineries and downstream units.

Lane noted construction inflation has roughly doubled project costs (alky units from ~$300-400M to ~$600M), making it harder to clear return thresholds against forward price assumptions, and confirmed interest in M&A through a processing/trading arbitrage lens.

Gary noted 460K bpd demand growth vs 415K bpd net additions for 2026, with many new facilities unable to reach nameplate and 1.5M bpd of Russian capacity offline.

Gary noted TMX barrels mostly flow to Asia, but broader quality differentials are widening (WCS at 12%, Maya at 14% discount to Brent), with OPEC and Canadian barrels starting to reach U.S.

Management stressed capital discipline: high-return reliability and yield projects, not market-timing bets.

CEO clearly delineated MPLX (mid-teens returns, nat gas/NGL focus) vs MPC refining (25% hurdle, yield optimization). No capital competition issue.

CEO and Rick described integrated value chain: MPC has natural gas short, MPLX supplies; commercial org optimizing through cogen and pipeline positions.

Rick called it unprecedented and inventory/supply-driven, lasting about 1-1.5 months; not structural. Demand hard data shows diesel/jet up modestly, gasoline flat, no slowdown.

Rick pointed to disproportionate crack responses to any disruption as evidence of structural tightness; strong diesel signals from over-the-road, containers, harvest; Russian drone attacks driving European diesel demand.

Wirth explained Australian volumes are largely termed to Asia while West Africa and North America feed Europe; strong JKM/TTF. Direct.

Wirth said timing effects are expected in rising price environments and will reverse. Company focused on maintaining supply, directing crude to refineries in tight markets, managing counterparty risks.

Bonner confirmed Permian at $3.5B CapEx ahead of target. Drilling efficiency more than doubled since 2022. Extending efficiency to DJ, Bakken, and Argentina through consolidated shale organization. Focus remains on growing cash flow not production.

Wirth attributed strong result to continued efficiency gains with fewer rigs and spreads. No change to plans to moderate growth and focus on cash generation. More detail at Investor Day.

Knop called the Zone 5 market one of the most lucrative in the continental US given LNG demand pull down Transco plus local Carolinas load, which is why EQT is building Southgate.

Jeremy indicated no direct near-term returns correlation with Q2 peak growth spending, just operational lumpiness in large-scale combo development.

Jeremy disclosed basis hedging reduced from ~90% historically to far less for 2026+; curtailments effectively serve as a natural basis hedge by withholding gas during price dislocations.

Toby said hyperscalers prefer simplicity, fixed rate per kWh, which creates opportunities for EQT to add cash flow durability through structured pricing; turbine orders sometimes looking for homes.

O'Brien addressed it directly, citing a structurally falling breakeven and the buyback lowering the absolute dividend burden as enabling top-quartile growth.

Andy O'Brien decomposed the trajectory: 2026 driven by OpEx/CapEx savings, 2027-2028 driven significantly by LNG (NFE, Port Arthur, NFS) with revenue plus CapEx rolloff. COP longer Henry Hub gas than LNG, $400M sensitivity per $1 on HH vs $200M on LNG.

Richard said midstream's core purpose is ensuring delivery of Oxy's product, with upside from marketing beyond equity volumes.

Babatunde cited Delaware secondary-bench development about 40% higher than the industry average, with activity expanded to the mid-40s.