Charles Meade

Mike said they valued storage by the earnings and repeatability it generates, not the asset in isolation.

Josh explained Q2 is CapEx peak due to slightly front-loaded D&C activity, leasehold acquisition closings, and seasonal workover ramp. Appalachia rigs come out in second half, moderating activity. Production grows modestly in Q3 and Q4 assuming market supports. Full year unchanged at 7.5 Bcf per day and $2.85 billion.

Mike said first threshold is strategic fit, then financial discipline with nonnegotiable accretion requirement. NG3 ownership, FT commitments, and storage equity stakes all evaluated on long-term value accretion basis. Approach has not fundamentally changed.

Josh described the sub-location program as having significant upside. Teams have been working on it and waiting for the right economic environment. Will leverage Haynesville deep gas drilling learnings. Expects highly profitable development but will require some infrastructure investment for processing.

Dan Turco explained storage added 3.5 Bcf in Q4 on top of 1.5 Bcf existing. Being actively used for volatility management with money already made. Would like to grow but market is highly competitive with demand outpacing capacity.

Josh clarified $2.75 is Haynesville-specific annual free cash flow breakeven including corporate items like dividend. Represents approximately $0.25 improvement from initial February guidance of approximately $3, reflecting drilling and productivity gains across 2025.

Josh said first priority is fine-tuning drilling operations in the area, then assessing early-time productivity and longer-term flow characteristics. Declined to speculate on 2026 plans until first well results are evaluated.

Josh reported 130 wells brought online over the last two quarters with no performance degradation from deferred timing. Natural variability across zones but overall execution very strong.

Nick pegged industry marginal breakeven loosely at mid-$3s and positioned Expand at the lower end, citing low-cost Marcellus inventory and best-in-class Haynesville capital efficiency.

Nick explained the framework as allowing production to fall below and rise above a target midpoint based on near-term market conditions, independent of the multiyear capital allocation decisions.

Kaes declined to opine on geopolitics, describing the market as a volatile sine wave and anchoring on inventories.

CEO cited Jamie Dimon advice on board communication. Sent 3-4 notes to board in March during crisis. Simple meeting ahead of earnings with resounding support for growth plan.

Al explained the Barnett and Woodford are distinct reservoirs separated by Miss Lime. Where Miss Lime is thin (basin center), they target lower Barnett and drain through to the Woodford.

Kaes said there were periods closer to red light in the past 6 months but oversupply hasn't materialized as aggressively; investors support flat production and max FCF while waiting for green.

Kaes said the green light triggers when OPEC barrels are absorbed and U.S. production starts struggling; cautiously optimistic about 2026 but hunkering down for rest of 2025.

Travis stated the letter was for stockholders but acknowledged awareness it would be widely read beyond that audience.

Christmann said acreage fits with existing footprint, most can tie into infrastructure. Both oil and gas prospectivity. Low-hanging fruit being pursued. Riney added acreage is spread out (not one big chunk), ranging from simple step-outs to new play concepts.

Riney explained fixed new gas price makes drilling economics equivalent to $75-80 Brent oil. Rising blended price over time as old PDP declines and new volumes come on. Analysis includes potential new infrastructure requirements.

Christmann confirmed fantastic results in northern Howard County with wider spacing. Plans to return with tighter spacing to increase inventory counts but declined to give specifics citing competitive sensitivity.

Christmann said operations are going well but declined to share results since they haven't reached pay zones yet. Noted things are 'on track' and 'very smooth.'

Kirk Johnson confirmed costs tracking to guidance. D26 rig incident had no impact, backfilled with active rig from existing units. Exploration and Willow predrill programs unaffected. Winter construction started early, nearing 50% complete. Permanent camp operational.

Andy O'Brien contrasted traditional stranded-gas model with Lower 48 commercial strategy connecting 2+ Bcf/d to TTF/JKM pricing, serving as natural hedge to US gas exposure.

Kirk Johnson detailed transition to year-round construction, Gulf Coast module fabrication continuing, 90-95% of contracts secured by year-end providing cost certainty.

Kirk Johnson detailed Nuna as first new pad in a decade, first oil in December, 8 more wells planned in 2025, expected to more than offset Alaska decline.

Keith said the two 1-mile wells tested the same zone and that future wells will test different landing zones across the concession.

Ezra drew parallel to Oman exit where EOG was transparent about results. Exploration phase has defined terms leading to declaration of commerciality and production license. Strong conviction in UAE oil and Bahrain gas opportunities. Interested in adding additional Gulf gas projects under right terms.

Keith said this was the largest remaining undeveloped core Eagle Ford block. Always looking for bolt-ons but they must compete on returns. Unlikely to find another block this large and undeveloped.

Jeff said discovery is early stage with reservoir model refinement ongoing. Platform specs and completion design in progress. Economics justify setting a platform. Engaging partners toward FID but declined to size production potential.

Clay explained $0.315 dividend aligns with Coterra's existing rate; combined with substantial share repurchase program for comprehensive returns.