Expand Energy (EXE) — Stock Analysis 2026 [4.2]

Analysis as of 6 September 2026. This is a point-in-time snapshot, not an evergreen guide. Fundamentals are from Expand Energy’s fiscal-2025 Annual Report (10-K, year ended 31 December 2025) and its Q2 2026 results, released after the close on 28 July 2026; market data is as of the 4 September 2026 close and will move. Rating: ★★★★, Solid — Overvalued (wide band) on a mid-cycle gas deck → full and then some: the market already sees it. Price deck used in the valuation: base Henry Hub US$3.00/MMBtu — the representative trailing average (3-month US$2.94, 6-month US$2.93) snapped to the fixed US$2.00–4.00 natural-gas grid — with every grid price run as a scenario, from US$2.00 to US$4.00; the EIA’s US$3.49 (2027) forecast is a 0%-weight cross-check and no spot deck is carried, and the company’s own reserve report is struck at a US$3.39/mcf NYMEX benchmark. 10% discount rate, the E&P convention for a sub-ten-year reserve life and the rate the standardized measure itself is struck at. Refreshed on each annual report and on material events. For information only, prepared with AI assistance — see the disclaimer at the end.

Expand Energy is the largest independent natural gas producer in the United States, and it is the company in this series where the valuation asks the reader to believe something specific and checkable: that Henry Hub settles near US$3.80 and stays there — gas’s own five-year average, held flat in perpetuity, against a reserve book that runs 9.9 years. At US$97.91 the shares sit at 2.4× a net asset value built off the company’s own audited after-tax reserve disclosure. The thesis in one line: a genuinely excellent operating business — the lowest cash costs and the lowest leverage in the peer group, 100% certified gas, an investment-grade balance sheet — priced for a gas market that has not arrived yet. Why look now: Q2 came in 19% ahead of consensus, the company has bought back US$849 million of stock and agreed a US$1.25 billion marketing acquisition, and it still has no permanent chief executive. To screen Expand against every North American upstream name on production, cost, reserve life and free-cash-flow yield, go to Metal Pilot.

1. Snapshot & thesis

Expand Energy Corporation (Nasdaq: EXE), formerly Chesapeake Energy Corporation, is a senior independent natural gas producer headquartered in Oklahoma City, Oklahoma. It is a producer/operator by archetype and an energy producer by sector, and it is the largest independent natural gas producer in the United States by net daily production. Its assets sit in three positions: the Haynesville and Bossier shales in Louisiana and Texas, the Marcellus in Northeast Appalachia in Pennsylvania, and the Marcellus and Utica in Southwest Appalachia in West Virginia and Ohio. In FY2025 it produced 7.18 billion cubic feet equivalent per day (bcfe/d) from working interests in approximately 6,600 gross (4,600 net) wells across 3.54 million net acres, operating about 99% of daily production volumes. (mcf = thousand cubic feet; mcfe = thousand cubic feet equivalent, liquids converted at 6 mcf per barrel; bcfe = billion; Tcfe = trillion; NGLs = natural gas liquids; GP&T = gathering, processing and transportation.)

Figure 1. Expand Energy in numbers

Figure data: Expand Energy FY2025 Form 10-K (production, reserves, PV-10, realized prices, unit costs); net debt per Q2 2026 results, 28 Jul 2026; market data and analyst consensus as of the 4 Sep 2026 close. Rating per Section 9; valuation read per Section 7.

Table 1. Expand Energy in numbers

Source: Expand Energy FY2025 Form 10-K for all operating and FY2025 financial figures; net debt, leverage, buybacks and 2026 guidance per Q2 2026 results (28 Jul 2026); market data and share count (231.50 m) per stockanalysis.com as of the 4 Sep 2026 close. Free cash flow is operating cash flow (US$4,575 m) less capital expenditures (US$2,736 m). Cash costs comprise production, gathering/processing/transportation, severance and ad valorem taxes and general and administrative expense. The share count is 231.50 m, down from 239.25 m at 31 December 2025 after US$849 m of 2026 repurchases — the valuation in Section 7 uses the current count throughout. Listed: Public (Nasdaq: EXE).

Thesis in brief. Bull: the best-run gas business in the group on the metrics that compound — total cash costs of US$1.29/mcfe and a cash margin of US$2.01/mcfe, both the best in the peer set; leverage of roughly 0.5×, the lowest; US$1.3 billion of debt shed in six months on an investment-grade balance sheet; 100% responsibly sourced gas certification; and Haynesville volumes sitting next to Gulf Coast LNG with a part-owned carbon-capture pipeline already in service. Bear: the reserve life is 9.9 years, the shortest in the peer set by more than five years, so the premium is not backed by duration; the 2025 reserve build came almost entirely from price revisions rather than discovery (extensions and discoveries added 52 Bcfe against 2,622 Bcfe produced); merger-stepped depletion of US$1.14/mcfe cuts the fully-loaded margin to US$0.87, below Range and CNX; and an interim chief executive has run the company since February 2026. What tips it: the gas deck. At the US$3.00 base price the net asset value is about US$41; at US$3.50 about US$61; at US$4.00 about US$80. The full rating is in Section 9.

How to read this analysis: here for the verdict? The statcards above and the rating in Section 9 are the whole story. Want the evidence? Read Section 2 (the assets) through Section 7 (the valuation).

2. Assets & operations

Expand sells into two different gas markets, which is the point of owning it. Henry Hub averaged US$2.94/MMBtu over the three months to August 2026, with the U.S. EIA forecasting US$3.49 for 2027; Haynesville molecules price close to that Gulf Coast benchmark and sit next to LNG export capacity, while Appalachian molecules carry the basin’s structural discount. For how gas is priced, who produces it and how basis works, see the Natural Gas — A Complete Market Guide ; the crude complex that sets the small NGL strip is covered in the Oil guide . This section spends its words on the company. For how Expand compares with the other four large US gas producers on one construction — scale, cost, reserve value, balance sheet and the nine-point scorecard — see US Upstream Natural Gas Producers Compared .

2.1 Portfolio overview & map

Expand’s portfolio is the product of one transaction. On 1 October 2024 it completed the Southwestern Merger, issuing approximately 95.7 million shares valued at about US$7.9 billion, and changed its name from Chesapeake Energy to Expand Energy — creating the largest independent US gas producer and roughly doubling both the Appalachian and Haynesville positions. That followed the 2023 exit from the Eagle Ford across three transactions for about US$3.5 billion, which completed the repositioning from a mixed oil-and-gas producer into a gas pure-play.

Table 2. Asset base, 31 December 2025

Source: Expand Energy FY2025 Form 10-K , acreage, production and reserve-mix tables at 31 Dec 2025. The three district acreage lines do not sum to the portfolio total, which includes other and legacy acreage. Reserve shares are the company’s disclosed split by volume. NG3 = New Generation Gas Gathering, a 35%-owned pipeline and carbon-capture joint venture with Momentum Sustainable Ventures. Listed: Public (Nasdaq: EXE).

The geographic split is real diversification rather than a legacy accident. Haynesville supplies 42% of production but only 23% of reserves — short-life, high-deliverability gas next to the Gulf Coast LNG corridor — while Northeast Appalachia is the mirror image at 36% of production against 42% of reserves, long-life dry gas at US$0.17/mcfe of operating expense, the cheapest in this series. Southwest Appalachia carries all of the liquids and realizes US$3.76/mcfe against Haynesville’s US$3.17 and Northeast Appalachia’s US$2.99. Expand can point capital at whichever of the three is winning.

2.2 Revenue split — by commodity & by district

By commodity, Expand is the purest gas play in this series. FY2025 revenue of US$8,476 million split roughly US$7,420 million natural gas (87.7%), US$724 million NGLs (8.6%) and US$318 million oil (3.8%), from realized prices of US$3.08/mcf for gas, US$24.48/Bbl for NGLs and US$54.47/Bbl for oil. Liquids are about 8% of volume, all of it from Southwest Appalachia.

Figure 2. FY2025 hydrocarbon revenue by commodity

Figure data: Expand Energy FY2025 Form 10-K ; derived from FY2025 annual volumes (2,409 bcf/yr gas, 29.6 mmbbl/yr NGLs, 5.8 mmbbl/yr oil) and realized prices, which reconcile to the reported US$8,476 m of natural gas, oil and NGL revenue to within 0.2%.

By district, the production split is the more useful cut, because it shows where the three different economics sit.

Figure 3. FY2025 production by district

Figure data: Expand Energy FY2025 Form 10-K , production and average sales price table by significant field, FY2025.

Read together, the cost stack is where Expand earns its rating. Against a realized US$3.30/mcfe including derivatives, it paid US$0.24/mcfe in production expense, US$0.91 in gathering, processing and transportation, US$0.07 in severance and ad valorem taxes and just US$0.07 in general and administrative expense — total cash costs of US$1.29/mcfe and a cash margin of US$2.01/mcfe, the best in this series (Range US$1.71, Antero US$1.27). The G&A figure is the clearest scale benefit anywhere in the group: at US$0.07/mcfe it is under a third of Range’s US$0.22.

The offset is accounting rather than cash. Depletion, depreciation and amortisation ran at US$1.14/mcfe — the highest in the peer set, because the Southwestern merger reset the carrying basis of the acquired assets — which cuts the fully-loaded margin to US$0.87/mcfe, behind Range’s US$1.26 and CNX’s US$1.17. Expand generates more cash per unit than anyone here and reports less profit per unit than most.

2.3 Haynesville — the LNG-adjacent engine

Haynesville produced 1,095 bcfe in FY2025 at a realized US$3.17/mcf, on 561,000 net developed and 184,000 net undeveloped acres across Louisiana and Texas. Operating expense of US$0.27/mcfe is the highest of the three districts, reflecting deeper, hotter wells — but the offset is location: Haynesville gas reaches the Gulf Coast LNG corridor without long-haul Appalachian transport, which is why it realizes eighteen cents more per mcf than Northeast Appalachia despite costing more to lift.

The strategic addition here is the New Generation Gas Gathering (NG3) pipeline, a joint venture with Momentum Sustainable Ventures in which Expand holds a 35% interest. It carries roughly 900 mmcf/d of firm contracted capacity and has an integrated carbon-capture component; it commenced operations in October 2025. It is a modest asset in valuation terms but a meaningful one strategically — it connects certified low-emission Haynesville gas to export demand with the carbon handled at the pipeline rather than at the wellhead.

The asset-level risk is the shortest reserve life in the portfolio: Haynesville is 42% of production against 23% of reserves, so it depletes fastest and needs the most continuous reinvestment.

2.4 Appalachia — the long-life half

The two Appalachian districts are the reserve base. Northeast Appalachia produced 958 bcfe of dry Marcellus gas at a realized US$2.99/mcf — the lowest price in the portfolio, because Appalachian basis is what it is — but at an operating expense of just US$0.17/mcfe, the cheapest in this entire series. It holds 42% of Expand’s proved reserves on 497,000 net developed and 207,000 net undeveloped acres.

Southwest Appalachia produced 356.2 bcf/yr of gas plus 5.8 mmbbl/yr of oil and 29.6 mmbbl/yr of NGLs — 569 bcfe — and is where the entire liquids business sits. It realizes US$3.76/mcfe, a 26% premium to Northeast Appalachia, on operating expense of US$0.31/mcfe. It holds 35% of proved reserves with the largest undeveloped position of the three at 349,000 net acres.

The two together illustrate the trade Expand has made: Appalachia supplies 77% of the reserves and 58% of the production; Haynesville supplies the deliverability and the market access.

2.5 Production, reserves & the ten-year book

Group production was 2,622 bcfe (2,621 bcfe) in FY2025, against 1,375 bcfe in 2024 — but that near-doubling is the Southwestern merger annualising, not organic growth: the merger closed on 1 October 2024, so 2024 contains one quarter of the combined business and 2025 contains four. 2026 guidance is 2,701–2,774 bcfe, with Q2 2026 delivering 2,730 bcfe at 92% natural gas.

Proved reserves at 31 December 2025 were 25,880 bcfe (25.9 Tcfe) — 22,575 bcf of natural gas, 491.9 million barrels of NGLs and 58.8 million barrels of oil — the largest reserve base in this series. The PV-10 was US$19,374 million (proved developed US$15,047 million, proved undeveloped US$4,327 million), with a standardized measure of US$17,126 million after US$2.2 billion of future income taxes, struck at US$3.39/mcf of gas and US$65.34/Bbl of oil and NGL — the same gas benchmark every peer in this series used, which makes the comparison in Section 7.2 unusually clean.

The number that shapes the rating is the ratio between those two: 25,880 bcfe of reserves against 2,622 bcfe of annual production is a 9.9-year reserve life — the shortest in the peer set by more than five years, and less than half Range’s 22.2. Expand holds the most gas and burns through it fastest.

Figure 4. Production by fiscal year, FY2023–FY2026E

Chart source: Expand Energy FY2025 Form 10-K for FY2023–FY2025 volumes; the 2026 bar is the midpoint of 2,701–2,774 bcfe guidance annualised (Q2 2026). The 2024-to-2025 step is the Southwestern merger annualising (closed 1 October 2024), not organic growth. Realized price reached US$3.30/mcfe in 2025 (Table 4) — that second series is carried in the table rather than overlaid.

2.6 Peer positioning

Expand’s peer set is the one used across this series for North American gas: EQT Corporation (NYSE: EQT), the largest Appalachian producer; Antero Resources (NYSE: AR), the liquids-rich Appalachian name; Range Resources (NYSE: RRC), the long-life southwest Pennsylvania operator; and CNX Resources (NYSE: CNX), the low-cost dry-gas counterpoint. Every “vs. peers” claim in this analysis uses that set.

Table 3. Quality-metric peer positioning, mid-2026

Source: each company’s FY2025 Form 10-K and 2026 guidance; EQT Q2 2026 results . Cash-cost definitions vary slightly by filer — Expand’s comprises production, GP&T, severance and ad valorem taxes and G&A; CNX’s figure is for its Shale segment and is not fully comparable at group level. “n/d” = not disclosed on a comparable basis in the sources used. Figures should be refreshed at publish.

Where Expand sits: first on scale, first on reserves, first on cash cost — and last on reserve life. It produces more than Antero, Range and CNX combined, at a lower unit cash cost than any of them, from a reserve base that will be exhausted in a decade at current rates. That combination is exactly what one would expect from a company assembled by merger to serve near-term LNG demand, and it is the tension the scorecard has to price.

3. Financials & balance sheet

FY2025 was Expand’s first full year as a combined company, and it delivered: natural gas, oil and NGL revenue of US$8,476 million inside total revenues of US$12,124 million, income from operations of US$2,471 million, net income of US$1,819 million (US$7.57 diluted) against a US$714 million loss in the 2024 stub year, and US$1,839 million of free cash flow from US$4,575 million of operating cash flow less US$2,736 million of capital expenditure.

Table 4. Three-year financial summary (US$ millions)

Source: Expand Energy FY2025 Form 10-K — consolidated statements of operations and cash flows and the long-term debt note. The 2024-to-2025 comparison is distorted by the Southwestern Merger, which closed on 1 October 2024, so FY2024 contains one quarter of the combined business and FY2023 none; the revenue and production growth rates are therefore not organic. A five-year series is not shown because the FY2025 filing presents three years and the pre-merger entity is not comparable; “—” marks figures not disclosed on a consistent basis. Free cash flow is operating cash flow less capital expenditures. Expand pays a base dividend of US$2.30 per share.

The balance sheet is the strongest part of the story and improving quickly. Expand ended 2025 with US$5,025 million of total debt — nothing maturing before 2029 — having cut it by roughly US$1.2 billion since the Southwestern merger, on a credit facility upsized to US$3.5 billion. By 30 June 2026 total debt had fallen a further US$1.3 billion to US$3.7 billion, with net debt of US$3.1 billion and leverage of roughly 0.5×, the lowest in the peer set. The balance sheet is investment grade, and the company joined the S&P 500 in 2025.

Capital returns follow a stated, and actually-followed, waterfall: the base dividend of US$2.30 per share, then US$1.0 billion of annual net-debt reduction, then 75% of remaining free cash flow through buybacks and additional dividends. FY2025 delivered US$765 million of dividends and US$100 million of buybacks — about US$865 million returned — alongside the debt reduction. The mix is unusually dividend-heavy for a gas producer; the buyback is the smallest in this series relative to market capitalisation.

Hedging is substantial and sits at a net gain. At 31 December 2025 the book comprised gas fixed-price swaps on 756 bcf, two-way collars on 1,143 bcf and three-way collars on 175 bcf, plus minor oil collars, at a combined mark-to-market net asset of US$307 million; basis-protection swaps manage locational differentials across the two delivery regions. The programme is sized to protect the cash flows behind the base dividend and the debt-reduction commitment.

Figure 5. Operating cash flow by fiscal year, FY2023–FY2025

Chart source: Table 4, this analysis; Expand Energy FY2025 Form 10-K and Q2 2026 results. Capital expenditures, capital returned (~US$865m in 2025) and total debt (US$5,025m at year-end falling to US$3.7 bn by mid-2026) are read from Table 4 and §3 rather than overlaid as additional series.

4. Management, strategy & corporate structure

4.1 Management & governance

This is the weakest link in an otherwise strong company, and it is recent. On 6 February 2026 the Board appointed Michael A. Wichterich — Chairman of the Board since February 2021 — as Interim President and Chief Executive Officer, replacing Domenic J. Dell’Osso, Jr., effective immediately. In connection with his separation, Dell’Osso also resigned from the Board of Directors, effective immediately, and will serve as an external advisor for a period. The language matters: an appointment “effective immediately” combined with a simultaneous board resignation is the signature of an unplanned departure rather than a managed succession.

Wichterich, 58, is serving his second stint as interim chief executive here — he held the role from April to October 2021 and was Executive Chairman to December 2022. He remains Founder and CEO of Three Rivers Operating Company LLC, a private Permian-focused E&P, and was previously CFO of Texas American Resources, New Braunfels Utilities and Mariner Energy. The rest of the senior team is intact: EVP and Chief Operating Officer Joshua J. Viets, previously in leadership at ConocoPhillips, and EVP, General Counsel and Corporate Secretary Christopher W. Lacy.

The question is unresolved: the largest independent gas producer in the United States, still integrating a US$7.9 billion merger, has no permanent chief executive, and the person filling the role also runs another E&P full-time and doubles as Chairman. The counterweight is continuity — Wichterich knows the business, the operating team is unchanged, and Q2 2026 came in 19% ahead of consensus.

4.2 Strategy & capital allocation

The stated strategy is to create resilient shareholder value through responsible development of scale gas assets while remaining a leading supplier to growing markets, improving margins through operating efficiencies, marketing and commercial initiatives, and financial discipline. Capital is directed to the projects offering the highest cash return on capital invested, with acquisitions and divestitures used opportunistically — a description that fairly summarises the Eagle Ford exit and the Southwestern combination.

Two forward commitments give it teeth. The variable-return programme prioritises the base dividend and annual net-debt reduction before any additional shareholder returns, which is a genuine constraint rather than a slogan — it is why FY2025 saw US$1.0 billion of debt reduction alongside US$865 million of returns. And the ambition to participate in the global LNG value chain, positioning supply to reach premium international markets, which is the strategic logic behind both the Haynesville weighting and the NG3 investment. Integration of the Southwestern combination remains the central operational task.

4.3 Ownership & corporate structure

Three structural facts define the entity. The first is the Southwestern Merger (§2.1): because it was all-share — 95.7 million shares issued, about US$7.9 billion — per-share value creation depends entirely on whether the promised efficiency and marketing benefits materialise against a share count that rose by roughly 60%.

The second is the 2023 Eagle Ford divestiture — three separate transactions totalling approximately US$3.5 billion — which completed the repositioning into a gas-focused producer and funded the balance sheet that made the Southwestern deal possible. The third is the New Generation Gas Gathering joint venture with Momentum Sustainable Ventures, in which Expand holds a 35% interest in a Haynesville pipeline and carbon-capture project that commenced operations in October 2025.

On the equity side the structure is simple: 231.50 million shares outstanding at 4 September 2026, no dual class, and a count that rose sharply with the merger and is now being trimmed in earnest — US$849 million bought back in the first half of 2026 alone, down from 239.25 million at year-end.

5. ESG & sustainability

Expand’s environmental position is among the strongest in this series, and like Range’s it is externally verified rather than self-asserted. 100% responsibly sourced gas certification across the portfolio gives customers independent verification of emissions performance on every molecule sold — a commercial asset for a producer whose strategy runs through LNG offtakers and utilities that increasingly buy on certified intensity. The company targets net-zero Scope 1 and 2 emissions by 2035.

The most concrete environmental commitment is capital, not policy. The NG3 pipeline joint venture carries an integrated carbon-capture component and has been operational since October 2025 — Expand is one of very few gas producers in this peer group with a carbon-capture asset actually in service rather than in study. On safety, the company has transitioned to a Serious Incident and Fatality prevention model aimed at proactive hazard identification, supported by a Stop Work Authority programme empowering any employee to halt work.

The balanced read: certification, an operating carbon-capture asset and a dated net-zero target put Expand at the top of this peer set alongside Range, and the certification is load-bearing for the LNG-linked strategy rather than decorative. Two caveats. The 2035 net-zero target covers Scope 1 and 2 only, leaving most lifecycle emissions untouched for a company selling 2.6 Tcfe a year; and the filing quantifies no methane-intensity figure of the kind Antero and Range disclose, so the certification is verified but the underlying number is not stated.

6. Risks

Table 5. Risk register

Source: Expand Energy FY2025 Form 10-K risk factors, MD&A, reserve and hedge disclosures; Q2 2026 results for post-year-end figures. Likelihood and impact are the author’s assessment.

The through-line is that Expand has solved almost every operating problem a gas producer can solve and is left holding two it cannot: the price and the clock. Costs, leverage, certification and market access are all best-in-group. What it lacks is duration — a 9.9-year reserve life means replacing reserves simply to stand still, while the market already pays for a gas price above the forecast strip.

The two risks that would break the thesis compound each other. The price requires roughly US$3.80 Henry Hub held flat; the reserve base gives less than a decade for that to arrive. A long-life producer can wait out a weak decade — Range’s 22-year book is for exactly that. Expand cannot: at 2,738 bcfe it must convert undeveloped acreage continuously, at whatever prices prevail. Layer on an interim chief executive with no named successor mid-integration, and the execution demand peaks where the leadership is least settled. Which price regime arrives is a macro question; Commodities Across the Cycle sets out where energy commodities lead and lag.

Figure 6. Risk heat-map

Figure data: this analysis; risks per the register above.

7. Valuation

Valuation as of 6 September 2026, in US dollars. Horizon: spot fair value. Price deck: base Henry Hub US$3.00/MMBtu — the representative trailing average snapped to the fixed US$2.00–4.00 grid (3-month US$2.94, 6-month US$2.93, 12-month US$3.59, all to end-August 2026 on the U.S. EIA monthly spot series, the twelve-month window carrying a January 2026 spike, so the shorter windows are the representative ones) — with every grid price run as a scenario (deep bear US$2.00 / bear US$2.50 / base US$3.00 / bull US$3.50 / deep bull US$4.00); the EIA’s US$3.49 (2027) forecast carried as a 0%-weight cross-check; no spot deck is carried, so the section does not age with the daily quote. Realized gas = Henry Hub less the US$0.31/Mcf differential FY2025 booked against the reserve report’s own US$3.39 benchmark. Discount rate 10%, the E&P convention for a sub-ten-year reserve life — the same rate the standardized measure is struck at — sensitised 8–12%. Share price US$97.91 (4 September 2026 close), 231.50 m shares, balance sheet as of 30 June 2026.

Expand is valued on the E&P producer archetype, run as a sum-of-the-parts over three claims — the proved developed reserve base, the proved undeveloped tranche the reserve report funds, and the 35% NG3 pipeline interest. The method behind the numbers is set out in the How to Value Commodity Stocks guide; this section applies it to Expand. The headline is a deck-to-value map, not a single number: the blended fair value is US$62.46/share at the US$3.00 base price, US$34.37 at US$2.50 and US$93.46 at US$3.50, and each US$0.50/MMBtu of Henry Hub is worth about US$19.4 of NAV/share (US$38.9 per US$1.00) — 47% of NAV/share per step, the steepest deck leverage in this series, because 22.6 Tcf of the 25.9 Tcfe book is dry gas on a thin net revenue margin. Table 11 lets a reader run the model at any gas price they hold. The tiers frame the structure: the producing base plus the whole bridge is worth US$29.03/share, the proved undeveloped tranche US$12.37 more, and the resource tier is empty because the filing publishes no drilling-inventory count. The section sets the current US$97.91 price against that map only in §7.6, where the rating and the flip prices are published.

7.1 Method selection

Expand is a producer, so the blend starts from the E&P-producer default in the valuation guide linked above (NAV/DCF 45% / EV/EBITDA 30% / a reserve- or flowing-unit read 25%). The third default is not carried: the guide’s EV/2P anchor is struck on oil-equivalent barrels, and at 6:1 it implies US$1.67 per mcfe against the US$0.75 Expand’s own audited PV-10 carries — 2.2× the company’s reserve value, which would price the reserves alone at US$43 billion against a US$25.7 billion enterprise value. It is set aside, reported unweighted in §7.5 and logged as a data gap; a gas-basis dollar-per-mcfe anchor would let it return. The substitute is P/CF at the archetype’s own 4.5× anchor — the guide publishes no yield anchor for this archetype — which puts two methods in the cash-flow family, held together at the 50% collinear ceiling with the NAV taking the balance: NAV/DCF 50% / EV/EBITDA 30% / P/CF 20%, a stated deviation driven by the substitution and the cap.

Table 6. Valuation method selection

Source: method-to-archetype mapping, anchors and the default weight set per The Commodity Investor, Part 11: How to Value Commodity Stocks , “The archetype is the unit of analysis” and “The valuation toolkit”; the E&P-producer default deviated to 50/30/20 for the reserve-multiple substitution and the collinearity cap, per “Putting it together”. Archetype in Section 1; target multiples derived in §7.3 from the archetype anchors, not from the Section 2.6 peer set, which stays a quality comparator. Input families: intrinsic 50% (single method), cash-flow 50% (two methods, at the collinear ceiling), asset & capacity 0% (anchor not sourceable for gas — see §7.6), transaction 0%.

7.2 Net asset value

Vehicle map. Expand holds almost everything directly: there is no listed subsidiary, no consolidated joint venture and no third-party interest ahead of the common equity, so the map is short and nothing inside one line can reappear as another.

Table 7. Vehicle map

Source: this analysis; reserves, the tranche split, the NG3 terms and the agreements register per the Expand Energy FY2025 Form 10-K , Item 1 (reserves) and Note 15 (Investments); the Twin Eagle consideration, funding and expected timing per the company’s 27 July 2026 announcement.

Tax basis and asset-retirement obligations. The reserve base is carried at the SEC after-tax standardized measure, so tax is inside the figure by construction (the disclosure’s own schedule) and the balance sheet’s US$1,613 m of net-operating-loss carryforwards, US$654 m of excess business-interest carryforward and US$107 m of tax credits sit behind it — neither charged nor credited again. That schedule runs at 12.4% of pre-tax future net revenue (US$4,603 m against US$37,002 m) because the pools shelter the early years, while an incremental dollar of gas price is taxed at the 22.8% marginal statutory rate (21.0% federal plus 1.8% state net of federal, FY2025 rate reconciliation) — the rate the deck adjustment uses, which makes the deck sensitivity slightly conservative on the upside. Future dismantlement and abandonment are already inside the reserve report’s development costs (ASC 932), so the bridge’s reclamation line prints in rows and names the US$724 m balance-sheet obligation it corresponds to; the relative legs in §7.3 still deduct it, because EBITDA does not carry it.

Stage risk (n/a). No asset in the model is pre-production. The proved undeveloped tranche is a booked SEC reserve category that must be developed within five years and whose US$6,397 m of future development costs are already charged inside the standardized measure, so it takes a 1.00 risk weight and neither the target P/NAV nor the discount rate carries a second charge. What that tranche is exposed to is the price: 4,998 Bcfe of the 2025 build came from upward revisions to previously classified acreage, not from discovery — a fact charged once, in the reserves driver of §7.3.

The per-asset NPV build. Every NPV the model carries is built here first, one block per tranche. The two reserve blocks are Expand’s own disclosed figure apportioned and moved to the deck; NG3 is at carrying value; only the deck term is an author construction, printed as terms rather than as a total.

Table 8. Per-asset NPV build — base case (US$3.00/MMBtu Henry Hub ≈ US$2.69/Mcf realized, 10%)

Notes to Table 8

1. The filing splits PV-10 by category (proved developed US$15,047 m, proved undeveloped US$4,327 m) but publishes the standardized measure only in total, so the after-tax figure is apportioned on the pre-tax split. The apportionment is exact by construction: 13,301 + 3,825 = US$17,126 m.
2. The deck term: 22,575 Bcf of gas reserves × (1 − 2.28% severance and ad valorem, FY2025’s US$193 m against US$8,476 m of hydrocarbon revenue) × (1 − 22.8% marginal statutory tax) × 0.5286 — the disclosure’s own discount ratio, the US$17,126 m standardized measure over the US$32,399 m of undiscounted future net cash flows (Note 18) — gives US$9,003 m per US$1.00/Mcf, or US$0.348 per mcfe of reserves. Liquids (8% of volume) are held at the reserve report’s US$65.34/Bbl deck: the grid moves the headline gas benchmark only.
3. The same ratio implies a flat-equivalent life of 13.9 years for re-discounting — the annuity that reproduces 0.5286 at 10% — and that is the profile the rate rows of Figure 8 move both reserve blocks on. It is longer than the 9.9-year reserve-life ratio because the undeveloped tranche produces late.
4. The carrying value includes US$29 m of capitalised interest. NG3 publishes no separate EBITDA (Expand’s share of its income was immaterial in 2025 and is recognised on a three-month lag), so a contracted-infrastructure anchor multiple cannot be struck; carrying value is the honest mark and it is not re-discounted by the rate rows.
5. The 10-K gives 6,600 gross (4,600 net) producing wells, 1,957 k net undeveloped acres and 205–235 gross wells planned for 2026, but no undrilled-location count, no type curve and no inventory life — so the row that would price the gas analogue of resource beyond the plan cannot be built from disclosure and is printed n/d rather than proxied. The bound is the balance sheet’s own US$5,478 m of unproved properties, US$23.66/share, and the company’s July 2026 corporate presentation is the document that would close it.

Source: the Expand Energy FY2025 Form 10-K , cited by the filing’s own Item and Note numbers with its printed labels quoted, so every figure can be found by searching the document. Filed marks a figure printed in the filing, Derived the arithmetic of rows above it, Input a parameter of this section. The value column is headed Value rather than US$m because a build that multiplies heterogeneous terms cannot hold one unit; the unit sits in the line item, and only the = rows are US$m. The one relationship the table cannot express is the parametric form the sensitivity grid runs across the deck and the rate: reserves(HH, r) = [17,126 + 9,003 × (HH − 3.39)] × AF(r, 13.9) ÷ AF(10%, 13.9).

Table 9. Per-asset model — base case (US$3.00/MMBtu Henry Hub ≈ US$2.69/Mcf realized, 10%)

Source: this analysis, from the Expand Energy FY2025 Form 10-K (Item 1 reserves and PV-10, Note 15 investments, Note 18 standardized measure) and the FY2026 guidance in the Q2 2026 results. Every NPV in the last column reproduces from its block in Table 8; this table adds the reserve, cost, capital, tax and discounting inputs behind those figures. One discount-rate treatment: the two reserve blocks re-discount on the Note 18 timing, the NG3 carrying value is held, and the grid’s notes say so.

Table 10. NAV build-up and equity bridge (base case — US$3.00/MMBtu Henry Hub, 10%)

Source: this analysis; the derivative, lease, contract-liability, working-capital, G&A and asset-retirement lines per the Expand Energy FY2025 Form 10-K balance sheet (p.85) and Notes 6, 7, 15 and 16; net debt per the Q2 2026 results (28 Jul 2026); share count and market data per stockanalysis.com , 4 Sep 2026 close. Bridge lines in the standard order, each printed even where empty on one of the five value-column states. The tiers sum to the published NAV/share: producing US$29.03 + development US$12.37 + resource US$0.00 = US$41.40 on unrounded inputs — and the producing tier alone sits 70% below the US$97.91 price, before the undeveloped tranche is counted. Values computed on unrounded inputs, printed to whole US$m and two decimals per share.

Figure 7. Sum-of-the-parts NAV build-up

Figure data: Table 10. Equity net asset value of US$9,585 m equates to US$41.40 per share; the producing tier alone is US$29.03. “Hedge & wkg cap.” nets the hedge mark (+307) against net working capital and restricted cash (−558).

Figure 8. NAV/share sensitivity — Henry Hub price × discount rate

Notes to Figure 8

1. Checksum — the bear column (US$2.50) at the 10% base rate: proved developed = 13,301 + 6,538 × (2.50 − 3.39) = US$7,482 m; proved undeveloped = 3,825 + 2,465 × (2.50 − 3.39) = US$1,632 m; + NG3 313 = US$9,427 m gross; − 3,067 + 307 − 1,025 − 558 = US$5,084 m ÷ 231.50 m = US$21.96.
2. Rate rows — they move the two reserve blocks and the capitalised G&A only, on the 13.9-year flat-equivalent profile the standardized measure’s own discount ratio implies (×1.118 at 8%, ×0.900 at 12%); the NG3 carrying value and every balance-sheet claim are held down each column.
3. Cost — a +10% shock to the US$1.15/mcfe of production and gathering cost (US$315 m/yr) takes NAV/share to US$33.70 (−18.6%); a +10% Henry Hub move to US$3.30 lifts it to US$53.07 (+28.2%), and with a 5% cost lag applied to that price move, US$49.22 (+18.9%) — the price line runs well ahead of the cost line, which is what a US$0.35/mcfe net reserve margin does in both directions.
4. FX — n/a, Expand reports and trades in US dollars.
5. Stage risk — n/a, no asset in the model is pre-production; the proved undeveloped tranche is a booked SEC category at a 1.00 weight (§7.2), so there is no risked tranche to step down a band.
6. Schedule slip — n/a, no development asset stands outside the reserve report’s own five-year development schedule, and that schedule’s capital is already inside the standardized measure.

Figure data: this analysis’ model (Tables 8–10), every cell recomputed at that column’s Henry Hub price and that row’s rate, never scaled from the base cell. Price columns are the fixed natural-gas grid, grid version 2026-09 (US$2.00–4.00); base case US$3.00 at 10%. A one-step (US$0.50) Henry Hub move shifts NAV/share by US$19.44, or ~47%; the deck sensitivity is tabulated in Table 11.

Deck sensitivity — what one US$0.50 step of Henry Hub is worth. The grid holds the recomputed values; this table names the slope between them, so a reader with a different gas view can move the valuation themselves. The NAV lines are linear across the whole grid, because the reserve blocks enter on the disclosure’s own linear price term; the cash-flow lines flatten below US$2.54, where the cash-tax line reaches zero.

Table 11. Deck sensitivity — value per US$0.50/MMBtu step of Henry Hub (US$/share unless stated; base rate, target multiples held)

Source: this analysis, Tables 8–10 and 18. % of base is each line’s per-step move divided by its own base-price value — a leverage read, which is why the NAV, sitting behind US$3.1 bn of net debt and a US$1.0 bn capitalised-overhead charge, shows a larger figure than the multiple. Linear over is the Henry Hub range on which the slope holds: ¹ NAV/share crosses zero at ~US$1.94, below the grid; ² the EV/EBITDA equity floors at ~US$1.52; ³ below ~US$2.54 the cash-tax line reaches zero and both cash-flow slopes flatten, and FCF/share crosses zero at ~US$2.49; ⁴ the scenario blend steps 22.67 → 28.09 → 31.00 → 35.41 because the multiples move ×0.10 per step with the deck. Every step is the difference between two recomputed grid prices of Figure 8, never a scaled figure. Forward EBITDA moves US$1,231 m per step (2,519 Bcf of gas volume, net of severance) and cash flow per share US$4.11. How to use it: start from the base-price values (NAV/share US$41.40, blended fair value US$62.46) and add or subtract the per-step figure for every US$0.50 of Henry Hub away from US$3.00 — a US$3.25 flat deck gives a NAV/share of ~US$51.1 and a held-multiple blend of ~US$73.5; for a reading that also lets the multiples move with the cycle, use the scenario columns of Table 18.

The P/NAV price map (unweighted). The NAV restated as a price map, off Figure 8’s base-rate row: for each of the five fixed P/NAV levels this series uses for producers and E&Ps, the share price it implies at every grid price — NAV/share at the deck × level. Read down a column for the deck you hold, across a row for the multiple you would pay; where today’s quote sits is said once, by the market-implied deck in §7.5.

Table 12. P/NAV price map — share price implied by each P/NAV level at each grid price (US$/share)

Source: this analysis, solved on Tables 8–10: each cell is the Figure 8 base-rate NAV/share at that column’s Henry Hub price (2.52 / 21.96 / 41.40 / 60.85 / 80.29) × the row’s P/NAV level. The levels are fixed for the series (0.50× to 1.50× in quarter steps), so two producers can be read column-for-column; Expand’s 0.90× target, derived in §7.3, reads US$37.26 at the base price, US$19.76 at US$2.50 and US$54.76 at US$3.50, between the 0.75× and 1.00× levels. Unweighted: it translates a multiple and a deck into a share price without reference to today’s quote, so the map stays readable as both move — parity at the base price is US$41.40, and the top of the map, 1.50× at US$4.00 gas, is US$120.44.

7.3 Relative valuation

At US$97.91 and 231.50 million shares, Expand’s market capitalisation is ~US$22.7 billion and enterprise value ~US$25.7 billion. This section values Expand standalone: each target multiple is the fixed anchor for the E&P-producer archetype moved by the signed drivers this post’s own scorecard has already scored. No peer multiples are tabulated here — reading Expand against EQT, Antero, Range and CNX on observed reserve and cash-flow multiples is the job of the sector comparison , on one shared basis. Forward metrics are struck on the FY2026 guidance year at the base deck. The US$3.00 base sits 20% below Henry Hub’s five-year average of US$3.74 (September 2021–August 2026) — inside the ±25% band that marks a cycle extreme — so the subject is treated as near mid-cycle, and the scenarios in §7.6 flex both the deck and the multiples together, one step at a time.

Table 13. Target-multiple driver line (one line, applied to every multiple)

Source: this analysis; each term is tied to one scored dimension, capped at ±10%, and no fact is charged under two labels. The driver set is the standard one — asset quality, cost position, reserves and replacement, balance sheet and capital allocation; management, jurisdiction and ESG (Dims 7–9) sit outside it and are scored in Section 9, which is why the interim-CEO question does not appear here. The reserves term charges the short life and the revision-driven build once; the proved undeveloped tranche is not haircut a second time in Table 9. The one line is applied, unchanged, to every anchor:

Target P/NAV = 0.80× anchor × 1.13 = 0.904 → 0.90× · Target EV/EBITDA = 5.0× anchor × 1.13 = 5.650 → 5.7× · Target P/CF = 4.5× anchor × 1.13 = 5.085 → 5.1×. Rounded figures are the ones used in every table below.

Table 14. Forward EBITDA build — FY2026 guidance year at the base deck

Source: this analysis; volumes and capital per the Expand Energy FY2025 Form 10-K and the FY2026 guidance reaffirmed with the Q2 2026 results. “Forward” is the next twelve months = the FY2026 guidance year; the volume ties to guidance with nothing added above it. The marketing book is excluded: FY2025 marketing revenue of US$3,163 m against US$3,160 m of marketing expense is a US$3 m margin, immaterial at this scale, and the pending Twin Eagle acquisition is bridged as neutral (Table 7). Reconciliation: run at the reserve report’s own US$3.39 benchmark this build gives US$5,303 m against FY2025’s actual US$5,091 m on 4.4% less volume — US$1.937/mcfe against US$1.943/mcfe, a 0.3% difference, so the forward build reproduces the company’s reported margin. Cost-basis note: the NAV rows use the reserve report’s own production costs with gathering netted inside its price line, while this build states gathering separately — a definition, not a gap.

Table 15. Relative valuation — implied value per share (base case)

Source: this analysis; archetype anchors (E&P: P/NAV 0.80×, EV/EBITDA 5.0×) per the valuation guide linked in §7, “The valuation toolkit”. The implied EV crosses the same claims as the NAV bridge — plus the US$724 m asset-retirement obligation, which the reserve report carries inside its development costs but EBITDA does not — and omits only the capitalised corporate G&A, which is already deducted inside the EBITDA build. Values computed on unrounded inputs. To run the same reserve and cash-flow multiples across every North American upstream name, screen the sector on Metal Pilot.

The two reads do not agree, and the gap is the whole valuation: US$89.48 against US$37.26, a factor of 2.4. It is the difference between capitalising one year of cash flow and discounting a finite reserve book. The multiple sees US$4.3 billion of EBITDA and applies a mid-cycle anchor; the NAV sees 25.9 Tcfe that runs out in under a decade, charges the US$6.4 billion of development capital the reserve report schedules to get the undeveloped half out of the ground, and stops. Expand spends US$2.85 billion a year — 66% of that EBITDA — to hold it flat, and the multiple charges none of it. That is the standard trap in valuing a high-decline shale producer on EBITDA, and it is why the NAV anchors the blend at 50% and the two cash-flow reads share the collinear ceiling.

7.4 Further weighted methods — P/CF support

The third weighted read is a cash-flow multiple on Expand’s forward cash flow, built from disclosed lines and taken at the archetype’s own P/CF anchor.

Table 16. P/CF support build — FY2026 guidance year at the base deck

Source: this analysis; interest paid, income taxes paid and depreciation, depletion and amortisation per the Expand Energy FY2025 Form 10-K cash-flow statement and its supplemental disclosure (Note 17); capital guidance per the same filing and the Q2 2026 results. Every trailing line sits on FY2025, the latest reported fiscal year.

The method lands at US$84.92 — beside the EV/EBITDA read rather than between it and anything, for the reason §7.3 gives, which is why the two share 50% rather than carrying 50% each. The caveat travels with it: at 5.1× forward cash flow the method assumes the cash flow repeats, when US$2.85 billion a year of capital is what makes it repeat and the book that capital draws on is the shortest in the peer set.

7.5 Cross-checks (unweighted)

Nine diagnostics locate the blend; none carries weight.

Table 17. Cross-checks — reported, reconciled, never weighted

Source: this analysis; the market-implied and flip prices solved on the Tables 8–16 model; reserve, cost, conversion and roll-forward figures per the Expand Energy FY2025 Form 10-K (Item 1, Note 17 costs incurred, Note 18 reserve quantities and standardized measure); Henry Hub history per the U.S. EIA monthly series, five-year window September 2021–August 2026; the trailing multiple and dividend-yield series, consensus and analyst count per stockanalysis.com , read 6 Sep 2026 on the 4 Sep close. The FY2024 trailing multiple is excluded from the range because the Southwestern merger closed on 1 October 2024, so that year’s EBITDA carries one quarter of the combined company against a full-year market capitalisation.

7.6 Scenarios & fair value

Every weighted method is re-run in every column of the Henry Hub grid — the same five grid prices as Figure 8 and Table 11, so the section reads on one price axis. Table 18 lists what changes per column above the values it produces: the deck moves one step at a time; because the base sits inside 25% of gas’s five-year average (§7.3) the subject is near mid-cycle, so the three target multiples step ×0.80 / ×0.90 / — / ×1.10 / ×1.20 with it; and the discount rate on the author-discounted rows steps out to 12% and 14% on the downside while holding at the 10% convention on the upside — a rate below the industry’s own floor would price a 9.9-year gas book as safer than the industry treats it at any price. The last memo row is the same blend with the multiples held, the linear version reproducible from Table 11.

Table 18. Scenarios & fair value — inputs, value per method and the blend by grid price (US$/share)

Source: this analysis; weights per §7.1, scenario names by offset from the base price. Base blend on a calculator: 0.50 × 37.26 + 0.30 × 89.48 + 0.20 × 84.92 = 18.63 + 26.84 + 16.98 = US$62.46 (on unrounded values, 62.460). Inputs behind the rows, by column: the flexed targets 0.72× · 4.56× · 4.08× / 0.81× · 5.13× · 4.59× / 0.90× · 5.7× · 5.1× / 0.99× · 6.27× · 5.61× / 1.08× · 6.84× · 6.12×; forward EBITDA US$1,882 m / 3,112 m / 4,343 m / 5,574 m / 6,805 m; cash flow per share US$7.13 / 12.45 / 16.65 / 20.76 / 24.86; cash tax US$0 m / 0 m / 258 m / 539 m / 820 m — it reaches zero below US$2.54 and both cash-flow rows flatten there. The hedge mark is held at +US$307 m in every column: the derivative note publishes notional volumes (2,484 Bcf of gas contracts) and fair values but no strikes, so the book cannot be re-marked against each column’s deck; the whole balance bounds the omission at ±US$1.33/share. Risk weights are 1.00 in every column — no tranche in the model is pre-production. The deep-bear NAV leg is floored at 0.00: at US$2.00 gas and a 14% rate the bridge returns negative equity (−US$0.34/share before the P/NAV), and a negative value is never blended. Illustrative scenarios, not forecasts.

Figure 9. Value per share by method and scenario

Source: Table 18; each cell recomputed at its column’s deck, rate and multiple flex, never scaled; data-level ranked 0–9 across the whole grid. The three methods fan out rather than cluster, and the fan is the finding: the two cash-flow reads carry the steepest deck leverage because nothing stands between EBITDA and the equity except fixed claims, while the NAV — which charges the development capital and stops at the end of the reserve book — is both lower and, at the bottom of the grid, the only method that goes to zero. Current share price US$97.91 (4 Sep 2026); market-implied deck ~US$3.80/MMBtu. The bracketed figure under each value is its change against the same row’s base-case value.

Conclusion. The blended base-case fair value is US$62.46, inside a US$11.70 (Deep Bear, US$2.00) – US$128.87 (Deep Bull, US$4.00) range, against a US$97.91 price — an implied −36.2%, Overvalued, published as Overvalued “(wide band)” because the deep-bear blend sits 88% below the price. At the base price the guidance-year free cash flow of US$1,005 m is a 4.4% yield on the US$22.7 bn market capitalisation — respectable, and about a third of what the price implies the reserve base is worth. Rating-flip prices: with the multiples held at their targets, the base blend crosses up into Modestly overvalued above ~US$3.14/MMBtu Henry Hub (+4.7% from the base price) and into Fairly valued above ~US$3.58 (+19.3%); Overvalued is the bottom band, so no downward flip exists. The one assumption that drives the downside is Henry Hub settling back at the US$2.00–2.50 grid prices it spent much of 2023–24 at, with the annual US$2.85 bn capital programme still needed to hold volumes flat.

The three methods do not cluster, and the spread is the finding rather than something to average away — §7.3 sets out why the NAV sits at less than half the EV/EBITDA read, and why it anchors the blend. What the price now requires is the tiers read against it: the producing tier plus the whole bridge is worth US$29.03/share, the proved undeveloped tranche another US$12.37, and a buyer at US$97.91 is paying a US$56 premium to that — for Henry Hub at ~US$3.80 held flat in perpetuity, full credit for acreage the filing does not size, and the Twin Eagle build-out delivering more than the US$1.25 bn it cost. Each of those may happen; the audited reserve report prices none of them, and the Street’s US$125.52 target underwrites more still. This is an analytical read of price against value, not a recommendation.

Assumptions box: valuation date 6 September 2026; balance sheet as of 30 June 2026 for net debt and shares, 31 December 2025 for the derivative, working-capital, lease, contract-liability and asset-retirement lines (the latest in the source set); horizon spot fair value. USD throughout — trading currency = model currency, no FX. Price decks: base Henry Hub US$3.00/MMBtu (the 3- and 6-month trailing averages, US$2.94 and US$2.93, snapped to the fixed grid, version 2026-09), run across the US$2.00–4.00 grid; the EIA’s US$3.49 (2027) forecast as a 0% cross-check — no spot deck is carried; constant-price, unescalated deck and costs, matching the SEC reserve convention, so the 10% rate is real. Discount rate 10% — the E&P convention for a sub-ten-year reserve life and a high-decline shale base, and the rate the standardized measure is struck at — sensitised 8–12% on the author-discounted rows; the NG3 carrying value does not re-discount; no jurisdiction premium (Dim 8 ★★★★★, 100% United States, so the band is +0%). Share basis 231.50 m (basic ≈ diluted); values per share to two decimals, multiples to two significant figures, on unrounded inputs. Cycle: base 20% below the five-year average of US$3.74 (Sep 2021–Aug 2026), inside ±25%, so deck and multiples flex together, one step per column; anchors E&P P/NAV 0.80×, EV/EBITDA 5.0×, P/CF 4.5× per the valuation guide linked in §7, one driver line (×1.13); metric basis forward FY2026 (guidance year); EBITDA before all capital and after G&A; net debt excludes operating leases; P/NAV form equity (market cap ÷ equity NAV); no peer multiples enter this section. Method weights NAV 50% / EV/EBITDA 30% / P/CF 20% — the E&P default deviated as §7.1 states. NAV provenance: Expand’s own disclosed after-tax standardized measure, apportioned on the filed PV-10 split and moved to the deck on a term built from the filing’s own gas volumes, tax reconciliation and discount ratio; NG3 at carrying value; tax basis the SEC schedule (basis 3), pools inside it; asset-retirement obligation inside the reserve report. Primary value yardstick P/NAV (equity form). Stage-risk placement n/a — no pre-production asset; every row at a 1.00 weight. Known data gaps: (1) drilling inventory beyond proved reserves n/d — the 10-K carries no undrilled-location count, type curve or inventory life; NAV understated, bounded by the US$5,478 m of unproved properties on the balance sheet (US$23.66/share), closed by the company’s July 2026 corporate presentation; (2) hedge strikes n/d — the derivative note gives notional volumes and fair values only, so the mark is held at +US$307 m across the columns rather than re-struck, bound ±US$1.33/share, closed by the Q2 2026 Form 10-Q, which would also refresh the 30 June 2026 derivative, working-capital and asset-retirement balances; (3) the maintenance/growth capital split n/d — the whole US$2.85 bn programme is treated as maintenance, which understates free cash flow before growth capital; (4) a gas-basis EV/reserve anchor n/d — the asset-family method is not carried (§7.1), closed by a dated upstream-gas dataset median; (5) Twin Eagle (US$1.25 bn, announced 27 July 2026, expected to close in Q3 2026) is bridged as neutral, the asset at its consideration against the borrowing that funds it. None changes the rating. To run the same net asset value and multiples across every North American upstream name, screen the sector on Metal Pilot.

8. Near-term catalysts (1–3 years)

Expand’s catalysts are mostly about converting scale into per-share value, and one of them is simply appointing a chief executive.

Table 19. Near-term catalysts (1–3 years)

Source: Expand Energy FY2025 Form 10-K (capital-return policy, debt, NG3, certification, reserves), the Q2 2026 results (28 Jul 2026), the Twin Eagle announcement (27 Jul 2026) and the U.S. EIA Short-Term Energy Outlook . Reserve-value elasticity per Section 7.2. Timing reflects company guidance and is not guaranteed.

The common thread is that most of these are already in motion and already in the price. The deleveraging is policy, the synergies are being captured, the LNG demand is forecast rather than speculative. The genuinely unpriced item is the leadership question — and the genuinely unhedgeable one is the gas deck.

9. Rating & verdict

Expand is scored on the Metal Pilot Company Scorecard — the same nine dimensions, on the same ★1–5 scale, that every North American upstream name in the series is scored on. As a producer/operator it takes the full rubric with no dimension marked not-applicable. Each star is relative to the peer set declared in Section 2.6 and substantiated below.

Table 20. The Expand Energy scorecard

Source: the Metal Pilot Company Scorecard; evidence in Sections 2–7. Peer basis: the North American gas producers named in Section 2.6 (EQT, Antero Resources, Range Resources, CNX).

Σ(weight × score) = 0.75 + 0.60 + 0.45 + 0.75 + 0.60 + 0.25 + 0.125 + 0.3125 + 0.3125 = 4.15/5 → 4.2/5, the figure in the title and the Section 1 tile, and ★★★★, Solid, on the half-star band the body publishes. Weighted by producer/operator archetype: dominant dimensions (asset quality, cost, reserves/life, balance sheet, capital allocation) at 15% each, the remaining four at 6.25% each.

The two-axis verdict. Quality Solid (★★★★) × Value Overvalued (wide band) → full and then some: the market already sees it. The quality axis is strong and unusually lopsided: four dimensions score ★★★★★ — scale, balance sheet, jurisdiction and ESG — against a ★★★☆☆ on reserve life and a ★★☆☆☆ on governance. A 9.9-year book and an interim chief executive are the two things a buyer at a premium would least like to find, and neither is cosmetic.

The value axis is where this analysis parts company with the market, and it turns on one number: the gas deck. The price implies Henry Hub at about US$3.80 held flat in perpetuity — gas’s own five-year average, against a three-month average of US$2.94 — over a book that gives an investor under a decade to be right, plus full credit for acreage the filing does not size. The company is not the problem; the price is. Section 7.6 has the blend, the range and the prices at which the read changes band. This is an analytical read of quality and price, not a recommendation.

To go from this single-name view to the whole peer group — screening every North American upstream producer on production, cost, reserve life, net debt and free-cash-flow yield — explore Metal Pilot.

10. Sources, methodology & disclaimer

10.1 Sources, methodology & data vintage

Company fundamentals, reserves, PV-10, production and realized prices by district, unit costs, acreage, hedge positions, structure, management and risk factors are from Expand Energy Corporation — 10-K Filing / Annual Report — 2025 (fiscal year ended 31 December 2025). Reserves are SEC-basis proved reserves at 31 December 2025 on the unweighted twelve-month average first-day-of-the-month prices — US$3.39/mcf of gas and US$65.34/Bbl of oil and NGL, before differentials — held flat for the life of the reserves; PV-10 is the disclosed pre-tax measure and the standardized measure its after-tax equivalent, and neither purports to be fair market value. Post-year-end developments — the 6 February 2026 appointment of Michael A. Wichterich as Interim President and CEO, Q2 2026 production, FY2026 guidance, the 30 June 2026 debt and net-debt figures, US$849 million of first-half repurchases and the 27 July 2026 agreement to acquire Twin Eagle Holdings for US$1.25 billion — are from the 10-K’s subsequent-events disclosure, the Q2 2026 results (28 July 2026) and the Twin Eagle announcement.

Market data (the US$97.91 close of 4 September 2026, the share count, market capitalisation and enterprise value, and the five-year trailing EV/EBITDA and dividend-yield series used in Section 7.5) and the 26-analyst Buy consensus are from stockanalysis.com , sourced from S&P Global Market Intelligence, read on 6 September 2026. The Henry Hub trailing and five-year averages behind the price deck are from the U.S. EIA monthly spot series; the 2027 forecast carried as a 0%-weight cross-check is from the U.S. EIA Short-Term Energy Outlook .

Methodology and its limits. The net asset value starts from the disclosed after-tax standardized measure, apportions it across the two proved tranches on the filed PV-10 split, moves it to the base deck, and bridges to equity — the arithmetic is in Tables 8–10. Two lines are author constructions: the deck term of US$9,003 million per US$1.00/mcf, whose every input is filed, and the US$1,025 million of capitalised corporate G&A the reserve report excludes; NG3 is at its filed carrying value. The drilling inventory beyond proved reserves is carried at n/d rather than proxied, because the 10-K discloses no undrilled-location count, type curve or inventory life — the company’s July 2026 corporate presentation would close that gap, and the Q2 2026 Form 10-Q would refresh the 30 June 2026 derivative, working-capital and asset-retirement balances and publish the hedge strikes the scenario columns need. The full data-gap register is in Section 7.6. One sanctioned adaptation: the asset-map figure is omitted — a proportional-symbol map of the three districts would not render legibly at this scale, so Table 2 and the §2.1 prose carry the footprint instead. Re-run log: 6 September 2026 — Section 7 was rebuilt to the current valuation method: the market layer was refreshed to the 4 September close (US$97.91, 231.50 m shares after the H1 buyback), the price axis was restated as the fixed US$2.00–4.00 Henry Hub grid (version 2026-09) with the three trailing averages printed, and the deck-sensitivity table, the P/NAV price map and the guidance-year free-cash-flow bridge were added. Net effect: NAV/share US$41.40, base blend US$62.46, implied return −36.2%, the value read unchanged at Overvalued (wide band). 7 September 2026 — corrections after a pre-launch audit, none of which moves a valuation figure: the composite is stated as 4.2/5 (the weighted average is 4.15, previously rounded down to 4.1 in the title and the Section 1 tile); the scorecard table is ordered by weight; the rate-row factors in Figure 8’s second note are restated as ×1.118 and ×0.900, the ratios its own 13.9-year flat-equivalent profile implies and the ones the printed cells already use. Data as of 6 September 2026; refreshed on each annual report and on material events. Provenance: Expand Energy Corporation — 10-K Filing — 2025.

10.2 Disclaimer & disclosure

This analysis is for informational purposes only and is not investment advice; do your own research or consult a licensed advisor. It is a point-in-time snapshot as of 6 September 2026 — share prices, multiples, analyst targets and the valuation read move, and reserve, production and net-asset-value figures are estimates as of the stated dates. PV-10 and standardized-measure figures are prepared under SEC pricing conventions and do not represent market value. The two-axis verdict is an analytical read of quality and price, not a personal buy or sell instruction. This report was prepared with AI assistance; figures were sourced from Expand Energy’s filings, the U.S. EIA and market data and reviewed, but readers should verify before acting. The author holds no position in Expand Energy as of the date of writing.