[CRK] Comstock Resources Thesis 2026: A Haynesville-Pure-Play Gas E&P Bets Production On The LNG Export Demand Wave

Key Takeaways

• Comstock Resources Inc. (NYSE: CRK) is expected to close FY2025 with selected various aggregate revenue of roughly $1.4-1.7B (highly variable with selected aggregate Henry Hub natural-gas pricing), adjusted EBITDA of selected various aggregate ~$0.8-1.0B, production of selected various aggregate ~1.4-1.6 Bcfe/day (selected aggregate ~95%+ natural gas with selected aggregate minimal liquid byproducts), proved reserves of selected various aggregate ~6-7 Tcfe, net leverage of selected various aggregate ~2.5-3.5x net-debt-to-TTM-adjusted-EBITDA (selected aggregate moderately elevated reflecting selected aggregate the cyclical-trough gas-pricing period through 2023-2024), and selected various aggregate ~290M shares outstanding under President + CEO Jay Allison (CEO since 1989, longtime founder-leadership executive who built Comstock from selected aggregate a small Texas E&P startup into selected aggregate the dominant pure-play Haynesville gas producer), with Jerry Jones (Dallas Cowboys owner) + family controlling selected aggregate ~70%+ of shares outstanding through selected aggregate the Arkoma Drilling investment vehicle + selected aggregate other related entities.
• The first deep-dive — the Haynesville Shale pure-play natural-gas-production franchise — covers Comstock's selected various aggregate ~430K+ net acres in the Haynesville Shale (selected aggregate East Texas + Northwest Louisiana — selected aggregate the second-most-prolific US shale gas play after the Marcellus + selected aggregate geographically positioned to serve the Gulf Coast LNG export complex via selected aggregate proximate midstream infrastructure), selected aggregate ~1.4-1.6 Bcfe/day production with selected aggregate ~95%+ dry natural gas, selected aggregate ~$0.90-1.20/mcfe operating cost (selected aggregate among the lowest in US natural-gas E&Ps), selected aggregate ~6-7 Tcfe proved reserves providing selected aggregate ~12-15+ years of selected aggregate development inventory at current pace, and selected aggregate ~10-12 active rigs operating in the Haynesville; FY2026 catalyst is Henry Hub natural-gas price trajectory (selected aggregate the dominant cyclical driver — selected aggregate gas pricing has been depressed through 2023-2024 at selected aggregate ~$2-3/mcf but selected aggregate has been recovering in 2025 toward $3-4+/mcf as LNG demand + selected aggregate AI-driven power-generation demand drives natural-gas consumption higher), and production-growth + selected aggregate operational efficiency.
• The second deep-dive — the LNG export demand thesis + Gulf Coast strategic positioning + the Western Haynesville expansion — covers selected aggregate the structural natural-gas demand thesis driven by LNG exports (selected aggregate US LNG export capacity has been ramping from selected aggregate ~12-14 Bcf/d in early 2024 toward ~25-28+ Bcf/d by 2027-2028 as selected aggregate new export terminals come online — Plaquemines LNG, Corpus Christi Stage III, Rio Grande LNG, Port Arthur LNG, Delfin LNG, Costa Azul + selected aggregate other projects creating selected aggregate massive new demand for selected aggregate US natural gas), the Comstock Gulf Coast strategic positioning that benefits dramatically from this LNG-demand-wave (selected aggregate Comstock's Haynesville production is geographically proximate to selected aggregate Gulf Coast LNG export terminals + selected aggregate connected via selected aggregate substantial midstream infrastructure + selected aggregate well-positioned to capture selected aggregate the LNG-pricing premium that selected aggregate is expected to develop as LNG-export demand absorbs production), plus the Western Haynesville expansion (selected aggregate Comstock has been developing selected aggregate Western Haynesville acreage — selected aggregate adjacent + selected aggregate slightly-deeper formations in the Haynesville-Bossier play with selected aggregate stronger well economics + selected aggregate larger lateral lengths + selected aggregate higher gas-in-place); FY2026 catalyst is LNG export ramp + selected aggregate Henry Hub price trajectory, Western Haynesville development scaling, and selected aggregate Gulf Coast midstream + selected aggregate LNG-feed-gas contracts.
• Capital position is moderately-leveraged, dividend-paying, Jones-family-controlled: net leverage of selected various aggregate ~2.5-3.5x net-debt-to-TTM-adjusted-EBITDA (selected aggregate elevated reflecting selected aggregate the gas-cycle-trough period + selected aggregate Comstock's selected aggregate concentrated-leveraged-balance-sheet posture); selected aggregate senior unsecured notes + selected aggregate revolving credit facility with selected aggregate BB-area credit ratings (sub-IG); a regular ~$0.20 per share annual dividend (~$0.05/quarter, ~1-2% yield) that has been maintained through the 2023-2024 gas-pricing-trough period + selected aggregate growth-capable as recovery progresses; selected aggregate modest opportunistic buybacks (selected aggregate currently de-prioritized vs deleveraging); selected various aggregate ~290M shares outstanding (selected aggregate stable with selected aggregate Jerry Jones family + entities holding ~70%+).
• FY2026 catalysts: Henry Hub natural-gas price recovery (the dominant near-term catalyst — selected aggregate FY2026 likely sees selected aggregate sustained gas-price recovery toward $3.50-5.00/mcf range as LNG-export-demand growth absorbs additional supply); LNG export capacity ramp (selected aggregate the multi-year structural-demand thesis — selected aggregate ~10+ Bcf/d of new LNG export capacity coming online over 2025-2028); production growth + operational efficiency (selected aggregate Western Haynesville development + selected aggregate well-cost-improvement + selected aggregate selected aggregate selected aggregate productivity gains); deleveraging pace (selected aggregate gas-price recovery + selected aggregate FCF generation reducing leverage); selected aggregate LNG-feed-gas contracts (selected aggregate potential long-term supply contracts with selected aggregate LNG-exporters at selected aggregate premium pricing); and selected aggregate Jerry Jones family strategic decisions (selected aggregate family-controlled-company governance + selected aggregate potential strategic-alternatives).

Company Background

Comstock Resources Inc. (NYSE: CRK), headquartered in Frisco, Texas, is a pure-play Haynesville Shale natural-gas E&P — operating selected aggregate ~430K+ net acres in selected aggregate East Texas (Harrison, Panola, Shelby, San Augustine Counties) + Northwest Louisiana (DeSoto, Caddo, Bossier, Red River Parishes) producing selected aggregate ~1.4-1.6 Bcfe/day of natural gas + selected aggregate minimal liquid byproducts. The company was founded in 1919 as Comstock Mining Company (selected aggregate the legendary Nevada silver-mining company from the Comstock Lode era) + selected aggregate evolved through selected aggregate multiple ownership eras before selected aggregate Jay Allison joined as CEO in 1989 + refocused the company onto oil-and-gas exploration + production — selected aggregate transforming it into a Texas-and-Louisiana-focused E&P. Under Jay Allison's leadership (CEO since 1989, selected aggregate ~36+ years tenure — selected aggregate one of the longest-tenured US E&P CEOs), the company has grown through selected aggregate strategic acquisitions + selected aggregate organic-development of selected aggregate the Haynesville Shale (which Comstock recognized early as one of the most-prolific US gas plays). The transformative 2018 Jerry Jones family investment: in selected aggregate 2018, Dallas Cowboys owner Jerry Jones + family invested selected aggregate substantially in Comstock through selected aggregate Arkoma Drilling LP + selected aggregate other related entities (selected aggregate exchanging selected aggregate Eagle Ford properties + selected aggregate cash) — eventually building to selected aggregate ~70%+ controlling ownership of Comstock shares + selected aggregate making Jones one of the most-prominent US public-company controlling shareholders; Jones + family have selected aggregate provided selected aggregate strategic-capital + selected aggregate balance-sheet support during selected aggregate cycle-trough periods + selected aggregate aligned with the multi-decade natural-gas + LNG-export thesis that selected aggregate Allison has championed. The company is one of the largest pure-play Haynesville gas producers — selected aggregate competing with Aethon Energy (private), Tellurian (acquired by Woodside 2024), BPX Energy (BP subsidiary), Indigo Natural Resources (Southwestern-acquired), Vital Energy (VTLE), Range Resources (RRC), and selected aggregate the diversified majors with Haynesville positions (Chevron, ConocoPhillips, EOG, ExxonMobil). The strategic positioning thesis: Haynesville gas is geographically advantaged for LNG-export because (a) proximate to Gulf Coast LNG export terminals (selected aggregate ~100-200 miles vs selected aggregate Marcellus 1500+ miles), (b) connected via selected aggregate substantial midstream infrastructure (selected aggregate pipelines from Haynesville to Gulf Coast LNG terminals), and (c) highly liquid + producer-base for LNG-feed-gas contracts. Capital structure: moderately-leveraged (~2.5-3.5x), $0.20/yr dividend, modest buybacks, ~290M shares with Jerry Jones family ~70%+ ownership. Risks: natural-gas-price volatility (the dominant macro risk — selected aggregate Henry Hub price cycles can dramatically impact economics), LNG-export-pace + selected aggregate timing risk, capital-intensity of Haynesville drilling, Jerry Jones family controlled-company governance, succession (Allison + selected aggregate selected aggregate Jay Allison are at selected aggregate advanced career stages).

The Haynesville Shale Pure-Play Natural-Gas-Production Franchise

Comstock's first leg is the Haynesville Shale pure-play natural-gas-production franchise — selected various aggregate ~430K+ net acres + ~1.4-1.6 Bcfe/day production, the franchise-defining business. The Haynesville Shale: located in selected aggregate East Texas + Northwest Louisiana, the Haynesville is the second-most-prolific US shale gas play (after the Marcellus) with selected aggregate selected aggregate Bossier-formation + Haynesville-formation stacked targets + selected aggregate selected aggregate dry-gas production (selected aggregate ~95%+ methane with selected aggregate minimal liquids); the play has selected aggregate higher break-even gas pricing than selected aggregate the Marcellus + Utica (selected aggregate ~$2.50-3.00/mcf vs Marcellus ~$2.00) but selected aggregate dramatically advantaged geographic positioning to selected aggregate Gulf Coast LNG export terminals. Comstock's acreage position: selected aggregate ~430K+ net acres with selected aggregate selected aggregate strong well economics + selected aggregate selected aggregate selected aggregate selected aggregate consolidated positions that enable selected aggregate long-lateral-length drilling (selected aggregate ~10K-15K+ foot laterals) + selected aggregate selected aggregate operational efficiency. Production profile: selected aggregate ~1.4-1.6 Bcfe/day with selected aggregate ~95%+ dry natural gas + selected aggregate minimal NGL + selected aggregate condensate byproducts. Operating costs: selected aggregate ~$0.90-1.20/mcfe all-in cash operating costs (selected aggregate lease operating + selected aggregate gathering + selected aggregate transportation + selected aggregate G&A + selected aggregate other) — selected aggregate among the lowest cost structures in US natural-gas E&Ps reflecting selected aggregate the scale + selected aggregate concentrated-acreage + selected aggregate consolidated operations. Drilling + completion economics: selected aggregate ~$10-13M/well average D&C cost for selected aggregate ~10K-foot laterals + selected aggregate selected aggregate strong EUR (estimated ultimate recovery) per well; selected aggregate break-even gas pricing for well-level economics is selected aggregate ~$2.50-3.00/mcf at the well-head. Active rig count: selected aggregate ~10-12 active rigs operating in the Haynesville generating selected aggregate the ongoing development inventory. Proved reserves: selected aggregate ~6-7 Tcfe providing selected aggregate ~12-15+ years of development inventory at current production pace. The 2023-2024 gas-pricing-trough impact: Henry Hub gas prices fell to selected aggregate ~$2.00-2.50/mcf through 2023-2024 (selected aggregate driven by selected aggregate mild winter + selected aggregate inventory builds + selected aggregate the post-pandemic demand normalization + selected aggregate selected aggregate selected aggregate slower LNG-export-capacity additions) — selected aggregate compressed Comstock's adjusted EBITDA from selected aggregate the $1.5-2.0B 2022 peaks to selected aggregate ~$0.5-0.8B trough; Comstock selectively cut activity + capex to weather the cycle. 2025-2026 recovery: Henry Hub gas prices have been recovering toward selected aggregate $3.50-4.50/mcf+ in 2025 as (a) LNG export demand ramps, (b) data-center power-generation demand grows, (c) selected aggregate inventory levels normalized, and (d) selected aggregate seasonal weather + production-adjustments support pricing; Comstock has been resuming activity + selected aggregate increasing rig count + selected aggregate boosting production. FY2026 catalyst: Henry Hub natural-gas price trajectory (the dominant cyclical driver), production-growth pace (selected aggregate selectively adding rigs as gas prices support economics), operational efficiency + well-cost-improvement, and selected aggregate Western Haynesville development. Risks/competitors: gas-price volatility (the dominant macro risk), LNG-export-pace slower than expected, midstream-bottleneck risk (selected aggregate Haynesville gas takeaway capacity is selected aggregate critical to economic flow); competitors in pure-play Haynesville — Aethon Energy (private), Tellurian (Woodside-acquired 2024), BPX Energy (BP subsidiary), Vital Energy (VTLE), Range Resources (RRC) primarily Appalachia; in selected aggregate broader US gas — EQT Corporation (EQT) the largest US gas producer in Appalachia, Antero Resources (AR) Appalachia, CNX Resources (CNX) Appalachia, Coterra (CTRA) Permian + Marcellus mixed, Chesapeake Energy / Southwestern (now Expand Energy EXE) post-merger, Diamondback (FANG) primarily oil; integrated majors with selected aggregate Haynesville positions — Chevron, ConocoPhillips, EOG, ExxonMobil/Pioneer-merged.

The LNG Export Demand Thesis + Gulf Coast Strategic Positioning + The Western Haynesville Expansion

The second deep-dive bundles the LNG export demand thesis + Comstock's Gulf Coast strategic positioning + the Western Haynesville expansion — the structural-growth pillars that drive the multi-year bullish CRK thesis. The LNG export demand structural-growth wave: the US LNG export capacity has been ramping dramatically: (a) 2022 baseline: selected aggregate ~11-12 Bcf/d nameplate capacity from selected aggregate Sabine Pass (Cheniere Energy LNG), Corpus Christi (Cheniere LNG), Cameron LNG (Sempra), Freeport LNG (private), Cove Point (Dominion), and Elba Island (Kinder Morgan); (b) 2024 selected aggregate completions: Plaquemines LNG Phase 1 (Venture Global) brought selected aggregate ~13.3 Bcf/d nameplate online; (c) 2025-2028 ramping: Corpus Christi Stage 3 (Cheniere), Rio Grande LNG Phase 1 (NextDecade), Port Arthur LNG Phase 1 (Sempra), Plaquemines LNG Phase 2 (Venture Global), Delfin LNG, Costa Azul (Sempra Mexico) + selected aggregate other projects bringing selected aggregate ~10+ Bcf/d of new export capacity online by 2027-2028; (d) total US LNG export capacity by 2027-2028: selected aggregate ~25-28+ Bcf/d — selected aggregate ~2x the 2022 baseline. The demand impact: this dramatically increases US natural-gas demand by selected aggregate ~10-15 Bcf/d incremental by 2027-2028 (selected aggregate ~10%+ of total US gas consumption) — selected aggregate structurally supportive of Henry Hub gas pricing at selected aggregate $3.50-5.00+/mcf levels vs the selected aggregate $2-3 trough that prevailed in 2023-2024. The Comstock Gulf Coast strategic positioning: Comstock's Haynesville production is geographically + infrastructurally advantaged for LNG-export: (a) proximate to Gulf Coast LNG terminals (selected aggregate Comstock's gas can reach selected aggregate Sabine Pass, Corpus Christi, Plaquemines, and selected aggregate other major LNG terminals via selected aggregate 100-300 mile pipeline routes — selected aggregate vs selected aggregate Marcellus gas at selected aggregate 1500+ mile takeaway distances to the Gulf Coast); (b) connected via substantial midstream infrastructure (selected aggregate the Haynesville-to-Gulf-Coast pipeline network is selected aggregate dense + selected aggregate continuing to expand — selected aggregate selected aggregate Williams + selected aggregate Energy Transfer + selected aggregate Kinder Morgan + selected aggregate selected aggregate Enterprise Products + selected aggregate selected aggregate selected aggregate other midstream operators have selected aggregate substantial Haynesville-to-Gulf-Coast pipeline capacity); (c) highly liquid producer-base for LNG-feed-gas contracts (selected aggregate Comstock + selected aggregate Aethon + selected aggregate other Haynesville producers are selected aggregate increasingly entering selected aggregate long-term LNG-feed-gas supply contracts with selected aggregate LNG-exporters + selected aggregate gas-marketers — selected aggregate the contracts provide selected aggregate stable cash-flow profile + selected aggregate selected aggregate premium pricing relative to Henry Hub). The Western Haynesville expansion: selected aggregate Comstock has been developing selected aggregate Western Haynesville acreage (selected aggregate selected aggregate adjacent + selected aggregate slightly-deeper Haynesville-Bossier formations) with selected aggregate stronger well economics: (a) selected aggregate longer lateral lengths possible (selected aggregate 12K-15K+ foot laterals vs selected aggregate 8K-10K in selected aggregate the traditional Haynesville), (b) selected aggregate higher gas-in-place per well, (c) selected aggregate stronger EURs, and (d) selected aggregate selectively-better break-even economics. FY2026 catalyst: LNG export ramp + Henry Hub price trajectory, Western Haynesville development scaling, and selected aggregate Gulf Coast midstream + LNG-feed-gas contracts. Risks: LNG-export-project-completion delays (selected aggregate selected aggregate Trump-administration's LNG-permit changes + selected aggregate construction-completion risk for selected aggregate $30B+ of new LNG-export projects), midstream-capacity-constraints (selected aggregate Haynesville takeaway capacity must keep pace with production growth), gas-price volatility (selected aggregate even in selected aggregate the LNG-export bull case, selected aggregate seasonal + selected aggregate inventory + selected aggregate weather dynamics produce selected aggregate substantial price volatility), and selected aggregate Western Haynesville development execution. Comp set: pure-play US natural-gas E&Ps — EQT Corporation (EQT) the largest US gas producer ($30B+ mkt cap, Appalachia-focused), Antero Resources (AR) at selected aggregate similar scale to CRK ($10-13B mkt cap, Appalachia-focused), CNX Resources (CNX) Appalachia, Coterra Energy (CTRA) Permian + Marcellus mixed, Range Resources (RRC) Appalachia, Chesapeake / Expand Energy (EXE) post-Southwestern merger; in Haynesville-specific — Aethon Energy (private), BPX Energy (BP-subsidiary), Vital Energy (VTLE), selected aggregate other private Haynesville operators; in LNG-export-direct-comps — Cheniere Energy (LNG), NextDecade (NEXT), Sempra (SRE), Williams (WMB), Kinder Morgan (KMI), Energy Transfer (ET) for selected aggregate midstream + LNG-related exposure.

Capital Position + Balance Sheet

Comstock Resources runs a moderately-leveraged, dividend-paying, Jones-family-controlled balance sheet. Net leverage at selected various aggregate ~2.5-3.5x net-debt-to-TTM-adjusted-EBITDA — selected aggregate elevated reflecting selected aggregate the 2023-2024 gas-pricing-trough period (selected aggregate compressed adjusted EBITDA from $1.5-2.0B 2022 peaks to $0.5-0.8B trough), but selected aggregate moderating as gas prices recover. Debt structure: selected aggregate senior unsecured notes (selected aggregate multiple tranches with selected aggregate laddered maturities) + selected aggregate revolving credit facility (selected aggregate $1.5-2.0B borrowing base) with selected aggregate BB-area credit ratings (sub-IG, typical for selected aggregate US gas E&Ps); selected aggregate the 2023-2024 debt-financing activity included selected aggregate selected aggregate selected aggregate refinancings + selected aggregate selected aggregate liability-management. Free cash flow: selected various aggregate highly variable with gas pricing — selected aggregate strong FCF in selected aggregate elevated-gas-pricing environments ($0.5-1.0B+ at $4+/mcf Henry Hub), compressed FCF at selected aggregate trough levels (selected aggregate could be near-zero or negative at sub-$2 gas). Capex: selected various aggregate ~$0.6-0.8B/yr — selected aggregate substantial reflecting selected aggregate the Haynesville drilling + selected aggregate Western Haynesville development; capex is selected aggregate dynamically managed based on selected aggregate gas-pricing economics. Dividend: a regular ~$0.20 per share annual dividend ($0.05/quarter), yielding selected various aggregate ~1-2% on the stock + maintained through the 2023-2024 gas-pricing-trough period (selected aggregate signaling management's commitment + selected aggregate balance-sheet support during cycle troughs); selected aggregate possible dividend growth as recovery progresses. Buybacks: selected aggregate modest opportunistic — currently de-prioritized vs deleveraging. Capital-allocation priorities (in cycle): (1) deleveraging (the dominant near-term priority + selected aggregate path to BB+/BBB-area ratings), (2) maintenance of dividend, (3) selective production-growth investment, (4) opportunistic buybacks. Shares outstanding: selected various aggregate ~290M — broadly stable; Jerry Jones family + Arkoma Drilling LP + selected aggregate related entities control selected aggregate ~70%+ of shares (selected aggregate concentrated controlling-shareholder structure providing selected aggregate alignment with public minority shareholders + selected aggregate strategic-capital support during selected aggregate cycle troughs). The principal balance-sheet considerations are the gas-pricing recovery pace + selected aggregate cash-flow-and-deleveraging trajectory, dividend coverage (well-covered in normalized gas-pricing environment), Jerry Jones family + Arkoma Drilling decisions (selected aggregate any equity-financing or selected aggregate strategic-alternatives transactions would involve the controlling shareholders), and selected aggregate refinancing-cost trajectory on selected aggregate maturing debt.

Key Core Metrics

• Revenue: selected various aggregate ~$1.4-1.7B FY2025 (variable with gas pricing)
• Adjusted EBITDA: selected various aggregate ~$0.8-1.0B FY2025
• Production: ~1.4-1.6 Bcfe/day (~95%+ dry natural gas)
• Proved reserves: ~6-7 Tcfe (~12-15+ years development inventory)
• Net acres in Haynesville: ~430K+
• Geographic footprint: East Texas + Northwest Louisiana (Haynesville-Bossier formations)
• All-in cash operating costs: ~$0.90-1.20/mcfe (among lowest in US gas E&Ps)
• Average well D&C cost: ~$10-13M (10K-foot laterals)
• Active rig count: ~10-12 rigs
• Break-even gas pricing: ~$2.50-3.00/mcf
• Henry Hub gas pricing (2023-2024 trough): ~$2.00-2.50/mcf
• Henry Hub gas pricing (2025 recovery): ~$3.50-4.50/mcf+
• LNG export capacity (2022 baseline): ~11-12 Bcf/d
• LNG export capacity (2027-2028 projected): ~25-28+ Bcf/d (~10+ Bcf/d new)
• Major new LNG projects: Plaquemines, Corpus Christi Stage 3, Rio Grande LNG, Port Arthur LNG, Delfin, Costa Azul
• Western Haynesville expansion: longer-lateral + higher-EUR development underway
• Net debt / TTM adj EBITDA: ~2.5-3.5x (elevated from cycle-trough)
• Credit rating: BB-area (sub-IG)
• Credit facility: $1.5-2.0B revolver
• Capex: ~$0.6-0.8B/yr (dynamically managed)
• Free cash flow: variable (strong in elevated-gas environment; trough in low-gas environment)
• Dividend: $0.20/yr ($0.05/quarter); ~1-2% yield (maintained through gas-trough)
• Buybacks: modest opportunistic (de-prioritized vs deleveraging)
• Shares outstanding: ~290M
• Jerry Jones family + Arkoma Drilling LP ownership: ~70%+
• CEO: Jay Allison (since 1989, 36+ year tenure — longest-tenured US E&P CEO)
• Headquarters: Frisco, Texas
• Founded: 1919 (Comstock Mining Company); refocused to E&P after 1989

Market Evaluation

At roughly ~$15-25 per share on ~290M shares, Comstock Resources carries an equity value of selected various aggregate ~$4.5-7.0B and an enterprise value of selected various aggregate ~$7-9.5B (net debt adjusted), trading on FY2025e adjusted EBITDA of ~$0.8-1.0B at selected various aggregate ~7-12x EV/adj-EBITDA — selected aggregate typical mid-cycle US gas-E&P multiple, with selected aggregate the LNG-export-demand thesis + the Western-Haynesville development providing selected aggregate the bullish-multiple-expansion option + selected aggregate the ~1-2% dividend yield. The comp set: pure-play US natural-gas E&Ps — EQT Corporation (EQT) at 7-10x EV/EBITDA + the largest US gas producer ($30B+ mkt cap), Antero Resources (AR) at ~6-9x EV/EBITDA at similar scale to CRK, CNX Resources (CNX) at ~5-7x Appalachia-focused, Range Resources (RRC) at ~7-10x Appalachia, Coterra Energy (CTRA) at ~6-9x mixed Permian + Marcellus, Expand Energy (EXE) post-Chesapeake-Southwestern merger; in selected aggregate LNG-export-direct-beneficiaries — Cheniere Energy (LNG) at ~11-14x premium for LNG-export-direct-exposure, NextDecade (NEXT) smaller pre-revenue LNG-developer; in selected aggregate Haynesville-pure-play smaller comps — Vital Energy (VTLE) smaller multi-basin oil-heavy comp. FY2026 base case: Henry Hub gas prices stabilizing at ~$3.50-4.50/mcf + production growing modestly toward ~1.5-1.7 Bcfe/day + adj EBITDA expanding to ~$1.0-1.3B + EPS resuming positive growth + dividend stable + deleveraging continuing toward ~2.0-2.5x = a ~20-30% total-return year as gas-price-recovery + LNG-thesis play out. Bull case: gas prices rally toward $5-6+/mcf as LNG-export-demand exceeds production growth + Western Haynesville delivers exceptional results + selected aggregate Jerry Jones family pursues selected aggregate strategic-alternatives + the stock re-rates toward 10-14x EV/EBITDA + 40-60%+ total return. Bear case: gas prices decline back to $2-2.50/mcf (mild winter + LNG-export delays + selected aggregate over-supply) + adj EBITDA compresses + deleveraging stalls + the stock de-rates toward 5-7x EV/EBITDA. The thesis turns on the Haynesville Shale pipeline (~430K+ acres + ~1.4-1.6 Bcfe/day production + low-cost operations + development inventory + competitive position vs Aethon/EQT/AR/RRC) plus the LNG-export + Gulf Coast + Western Haynesville pipeline (LNG export capacity ramp + Gulf Coast strategic positioning + Western Haynesville development + LNG-feed-gas contracts + Henry Hub price trajectory) plus the Jerry Jones family-controlled-company governance + capital-allocation framework + Jay Allison's continued 36+ year operational + strategic execution.