Antero Resources (AR) — Stock Analysis 2026 [3.7]

Analysis as of 6 September 2026. This is a point-in-time snapshot, not an evergreen guide. Fundamentals are from Antero’s fiscal-2025 Annual Report (10-K, year ended 31 December 2025) and its Q2 2026 results, released 29 July 2026; market data is as of the 4 September 2026 close and will move. Rating: ★★★½ (3.7/5), Solid — Overvalued (wide band) on a mid-cycle deck → the HG synergy is worth about one rating band, and the price already assumes more. 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, NGLs and oil held at their FY2025 realisations; the EIA’s US$3.49 (2027) forecast is a 0%-weight cross-check and no spot deck is carried. 10% discount rate, the E&P convention for a single-basin producer 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.

Antero Resources sells the richest barrel-equivalent in Appalachia and pays the highest toll to get it to market. In FY2025 it realised US$3.99 per thousand cubic feet equivalent — 45% more than its nearest dry-gas neighbour — and handed US$2.27 of every US$3.99 to gatherers, processors and pipelines. The thesis in one line: a newly-enlarged, investment-grade Marcellus pure-play whose US$2.8 billion HG acquisition is guided to cut corporate cash costs by thirty cents an mcfe, which is the difference between a mid-pack margin and a good one. Why look now: the deal closed in February, the Utica was sold to help pay for it, and management says leverage hits 1× by mid-2026 — six months early. To screen Antero against every North American upstream name on production, cost, reserve life and free-cash-flow yield, go to Metal Pilot.

1. Snapshot & thesis

Antero Resources Corporation (NYSE: AR) is an independent oil and natural gas exploration, development and production company headquartered in Denver, Colorado, operating entirely in the Appalachian Basin. It is a producer/operator by archetype and an energy producer by sector, reporting three segments: exploration and production, an equity-method 29% interest in Antero Midstream Corporation (NYSE: AM), and marketing of excess firm transportation capacity. What distinguishes it from every other Appalachian producer of this scale is product mix: 38% of its proved reserves are natural gas liquids and oil rather than dry gas. In FY2025 it produced 3.44 billion cubic feet equivalent per day (bcfe/d) from 1,551 net proved developed wells across 536,526 net acres, with 632 employees. (mcf = thousand cubic feet; mcfe = thousand cubic feet equivalent, with liquids converted at 6 mcf per barrel; bcfe = billion cubic feet equivalent; Tcfe = trillion; NGLs = natural gas liquids — ethane, propane, butanes and natural gasoline; GP&T = gathering, compression, processing and transportation.)

Figure 1. Antero Resources in numbers

Figure data: Antero Resources FY2025 Form 10-K (production, reserves, realized prices, unit costs, cash flow); Q1 and Q2 2026 results for net debt and guidance; market data, the Antero Midstream quote and analyst consensus as of the 4 Sep 2026 close. Rating per Section 9; valuation read per Section 7.

Table 1. Antero Resources in numbers

Source: Antero Resources FY2025 Form 10-K for all operating and FY2025 financial figures; net debt and 2026 guidance per Q1 2026 results (long-term debt of US$2.66 bn at 31 Mar 2026); market data and share count (307.44 m) per stockanalysis.com as of the 4 Sep 2026 close; Antero Midstream market capitalisation of US$10.73 bn at the same close. Net debt here uses the company’s filed long-term debt; note that some data providers report a materially higher “total debt” for Antero because they capitalise lease and transportation obligations — the filed figure is used throughout this analysis. Free cash flow is operating cash flow (US$1,631 m) less the US$797 m of capital expenditures reported in the MD&A. Listed: Public (NYSE: AR).

Thesis in brief. Bull: Antero is the only Appalachian producer at scale with a genuine liquids business — 38% of a 19.1 Tcfe reserve base — and it has just bought 385,000 net acres of core West Virginia Marcellus for US$2.8 billion while selling the non-core Utica for US$800 million, a swap that lifts 2026 production ~20% to 1,497 bcfe and is guided to take US$0.30/mcfe out of corporate cash costs. It is investment-grade, hedged above the market, and trades at roughly 8.5× forward earnings. Bear: its cost structure is the worst in the basin — US$2.27/mcfe of gathering, processing and transport against CNX’s US$0.54 — sitting on top of US$8.2 billion of minimum-volume commitments running to 2058 that it must pay whether it produces or not; the liquids premium does not currently cover that toll on a fully-loaded basis. What tips it: whether the HG cost synergy is real and durable, because on today’s numbers the stock is priced at about one times a risked net asset value with the synergy only partly credited. The full rating and its rationale are 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

Antero earns two prices, and only one of them is the gas price. 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; the other half of the revenue line tracks Mont Belvieu propane, butane and ethane, which price off crude and off international arbitrage rather than off the domestic gas balance. That split is the whole point of owning this company. For how gas is priced, who produces it and how the Appalachian basis discount works, see the Natural Gas — A Complete Market Guide ; the crude complex that sets the NGL strip is covered in the Oil guide . This section spends its words on the company. For how Antero 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

Antero’s portfolio is one basin, one formation and — after February 2026 — one state. At 31 December 2025 it held 536,526 net acres, of which 293,451 were developed and 243,075 undeveloped, with 86% of the net Appalachian position held by production. Two transactions announced on the same day in December 2025 reshaped it: the HG Acquisition added approximately 385,000 net acres in the core Marcellus of West Virginia for US$2.8 billion, and the Utica Shale Divestiture sold approximately 80,000 gross (70,000 net) acres in Ohio, carrying about 600 bcfe of proved reserves, for US$800 million. Both closed in February 2026.

Table 2. Asset base, 31 December 2025 and pro forma

Source: Antero Resources FY2025 Form 10-K , acreage table and Acquisitions/Divestitures; HG and Utica terms per the same filing and Q1 2026 results. WI = working interest. HG reserves are not separately disclosed in the FY2025 filing, which does not give effect to either transaction; the pro forma acreage line is derived (536,526 − 70,000 + 385,000) and the pro forma reserve line removes the disclosed ~600 bcfe of Utica reserves only. The Marcellus net acreage figure is derived as the residual. Listed: Public (NYSE: AR).

The concentration cuts both ways. Antero is now a single-basin, effectively single-state operator with no geographic diversification whatsoever — but it is concentrated in the one part of Appalachia that offers a real liquids window, and the Q1 2026 disclosure that HG added “nearly 400,000 net acres and 400 drilling locations” to the core West Virginia position means the inventory runway extends well past a decade at the current 70–80 wells a year.

2.2 Revenue split — by commodity & the cost stack

By commodity, Antero is the most balanced producer in the basin. FY2025 hydrocarbon revenue of US$5,010 million split US$2,873 million natural gas (57.3%), US$1,987 million natural gas liquids (39.7%) and US$150 million oil (3.0%) — against a production mix that is only ~36% liquids by volume, because a barrel of C3+ NGLs sold for US$38.83 while an mcf of gas sold for US$3.56. That is the liquids premium in one comparison, and it is why Antero realised US$3.99/mcfe when CNX realised US$3.04 on the same basis.

Figure 2. FY2025 hydrocarbon revenue by commodity

Figure data: Antero Resources FY2025 Form 10-K , consolidated statements of operations — natural gas sales US$2,873 m, NGL sales US$1,987 m, oil sales US$150 m. Excludes commodity derivative gains, marketing revenue and VPP amortisation.

Where that premium goes is the second, more important cut. Antero’s operating costs are not a mine’s costs; they are a toll booth’s. Against the US$3.97/mcfe realised after derivatives, the company paid US$2.27/mcfe in gathering, compression, processing and transportation — up from US$2.13 in 2023 — plus US$0.11 lease operating, US$0.13 production and ad valorem taxes, US$0.05 net marketing and US$0.14 general and administrative. That leaves a cash margin of US$1.27/mcfe, and after US$0.60 of depletion, depreciation and amortisation, a fully-loaded margin of US$0.67/mcfe.

Figure 3. Where the US$3.97 goes — FY2025 unit economics

Figure data: Antero Resources FY2025 Form 10-K , Production, Price and Cost History table. Cash margin is derived as the realized price after derivative settlements less the five cash cost lines; it excludes depletion, depreciation and amortisation of US$0.60/mcfe. This figure substitutes for the standard by-asset revenue split, because Antero operates a single basin and the cost stack is the more informative cut — see Section 10.1.

Read together: Antero earns the highest revenue per unit in Appalachia and keeps among the least of it. For comparison, CNX’s Shale segment realised US$2.70/mcfe against US$0.54/mcfe of transportation, gathering and compression. Antero’s realised price is US$1.27/mcfe higher; its midstream cost is US$1.73/mcfe higher. On a fully-loaded basis the liquids-rich model currently destroys about fifty cents an mcfe of margin relative to the low-cost dry-gas model — which is precisely the gap the HG acquisition is meant to close.

2.3 The core Marcellus — the producing engine

Everything Antero owns of consequence is in the Marcellus of West Virginia. FY2025 production was 1,256 bcfe (3,442 MMcfe/d): 808 bcf of natural gas, 29,842 MBbl of ethane, 42,010 MBbl of C3+ NGLs and 2,899 MBbl of oil, from 1,551 net proved developed wells. Realised prices were US$3.56/mcf for gas, US$11.91/Bbl for ethane, US$38.83/Bbl for C3+ NGLs and US$51.80/Bbl for oil. The company completed 61 net horizontal wells in 2025 on US$797 million of capital — US$658 million of drilling and completion, US$131 million of leasehold and US$8 million of other.

The rock quality shows in the reserve report rather than the cost line. Proved undeveloped reserves of 4,671 bcfe (24% of the total, up 12% on the year) need an estimated US$2.3 billion of development capital over five years — US$0.49/mcfe — a low conversion cost that reflects both the repeatability of the play and gathering infrastructure that already exists. Against that, the company took a downward revision of 300 bcfe for locations not drilled within five years of booking, a reminder that deep inventory only counts if it gets drilled.

The single most important asset-level risk is not geological. It is that all of Antero’s West Virginia, Ohio and Pennsylvania gas gathering and compression is contractually dedicated to Antero Midstream, with a right of first offer over processing and fractionation on top — so the operator cannot shop the toll.

2.4 The HG acquisition — the transformation

On 5 December 2025 Antero agreed to acquire 100% of HG Energy II Production Holdings, LLC for US$2.8 billion in cash, adding approximately 385,000 net acres in the core Marcellus of West Virginia; under the same agreement Antero Midstream agreed to buy HG Energy II Midstream Holdings for US$1.1 billion, taking the gathering pipelines and integrated water assets. Both closed on 3 February 2026. Between closing and 31 March the HG assets contributed US$246 million of revenue and US$116 million of net income — an annualised run-rate that, against the US$2.8 billion price, implies a mid-single-digit cash-flow multiple.

Three things make this more than a bolt-on. First, scale: 2026 production guidance of 1,497 bcfe is nearly 20% above 2025, achieved without a proportionate rise in overhead. Second, cost: management guides that HG will reduce corporate cash costs by US$0.30 per mcfe — on ~1,500 bcfe of annual production that is roughly US$450 million a year, which against a FY2025 cash margin of US$1.27/mcfe would be a 24% improvement in unit profitability. Third, mix: HG’s production is described as dry gas sold locally in the Appalachian Basin, which dilutes the liquids weighting but also dilutes the firm-transport burden, because those molecules do not need long-haul capacity. The asset-level risk is integration and the possibility that the guided synergy proves optimistic — the analysis in Section 7 credits only 60% of it in the base case.

2.5 Antero Midstream & the portfolio moves

Three other structures matter to the economics. First, the 29% equity interest in Antero Midstream Corporation, held on the equity method: it contributed US$98 million of equity in earnings and US$125 million of cash dividends in FY2025, and at Antero Midstream’s mid-July 2026 market capitalisation of US$10.52 billion the stake is worth roughly US$3.05 billion — about 29% of Antero Resources’ entire market value — while sitting on the balance sheet at book. It is simultaneously the largest non-operated asset and the counterparty extracting the US$2.27/mcfe toll; roughly a quarter of that toll comes back through the stake.

Second, the Utica Shale Divestiture, closed February 2026 for approximately US$740 million of net cash proceeds and a US$46 million gain, removing about 600 bcfe of proved reserves and the entire Ohio position. Third, the drilling partnerships: under the 2021–2024 partnership with QL Capital Partners, an affiliate of Quantum Energy Partners, QL funded 20% of development capital for wells spud in 2021 and 2024 and 15% in 2022–2023 for a proportionate working interest, with Antero taking a total carry of US$117 million; a 2025 partnership with an unaffiliated third party conveys a 15% working interest in that year’s wells. These bring third-party capital into a capital-hungry programme, and they are why a noncontrolling-interests line sits between operating income and earnings per share.

2.6 Production, reserves & costs (consolidated)

At the group level Antero produced 1,256 bcfe in FY2025, essentially flat on 1,252 bcfe in 2024 and 1,238 bcfe in 2023 — a maintenance programme, not a growth one, until HG changed it. Proved reserves at 31 December 2025 were 19,149 bcfe (19.1 Tcfe): 11,770 bcf of natural gas, 1,208 mmbbl of NGLs and 22 mmbbl of oil, or 38% liquids, up 7% on the year. The resulting reserve life is 15.2 years at 2025 rates. The PV-10 was US$9,679 million and the standardized measure US$8,110 million after US$1,569 million of discounted future income taxes.

Figure 4. Production by fiscal year, FY2023–FY2026E

Chart source: Antero Resources FY2025 Form 10-K for FY2023–FY2025 volumes; the 2026 bar is the 1,497 bcfe guidance annualised (~1,497 bcfe) per Q1 2026 results — a guidance figure, not an actual. Realized price including derivatives moved US$3.43 → 3.30 → 3.97/mcfe (Table 4) — that second series is carried in the table rather than overlaid.

The forward profile is where the story turns. 2026 guidance of 1,497 bcfe on a capital budget of US$1.1–1.3 billion — US$1.0 billion of drilling and completion, US$100 million of leasehold and up to US$200 million of discretionary growth capital contingent on prices — and 70 to 80 net horizontal wells against 61 in 2025. This is the first genuine production step-up Antero has delivered in years, and it was bought rather than drilled.

2.7 Peer positioning

Antero’s peer set is the same one used across this series for Appalachian gas: EQT Corporation (NYSE: EQT), the basin’s largest producer; Expand Energy Corporation (Nasdaq: EXE), the largest US gas producer by volume; Range Resources Corporation (NYSE: RRC), the closest analogue on liquids-rich southwest Pennsylvania acreage; and CNX Resources Corporation (NYSE: CNX), the low-cost dry-gas counterpoint. Every “vs. peers” claim in this analysis — each scorecard star, the cost read, the valuation multiples in Section 7 — uses that set.

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

Source: company guidance and filings as reported — Antero and CNX per their FY2025 Form 10-Ks and Q1 2026 guidance; EQT Q2 2026 results (2026 guidance 2,375–2,450 bcfe); Expand Energy Q2 2026 results ; Range Resources Q2 2026. Liquids mixes are approximate and on differing bases; “n/d” = not disclosed on a comparable basis in the sources used. Figures should be refreshed at publish.

Where Antero sits: mid-scale, uniquely liquids-weighted, with the longest reserve life alongside CNX and the highest revenue per unit in the group — and the highest cost per unit by a wide margin. It is roughly two-thirds of EQT’s size and more than double Range’s. The scorecard has to weigh a genuinely differentiated revenue line against a genuinely disadvantaged cost line, and that tension is the whole company.

3. Financials & balance sheet

FY2025 was Antero’s best year since the 2022 spike, and unlike many gas-company recoveries this one showed up in cash. Total revenue was US$5,276 million, up 22%, on natural gas sales of US$2,873 million, NGL sales of US$1,987 million and oil sales of US$150 million. Operating income was US$884 million against essentially breakeven in 2024, and net income attributable to Antero was US$634 million (US$2.03 diluted) after US$40 million attributable to the drilling-partnership noncontrolling interests. Operating cash flow of US$1,631 million against US$797 million of capital expenditure produced US$834 million of free cash flow — a genuine inflection from the US$133 million of 2024 and the negative figure of 2023.

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

Source: Antero Resources FY2025 Form 10-K for FY2023–FY2025 revenue, operating income, net income, EPS, unit prices and costs, operating cash flow and the year-end debt schedule; stockanalysis.com (Fiscal.ai, from Antero’s filings) for FY2022 and for the free-cash-flow series, which is operating cash flow less cash capital expenditures and therefore differs slightly from the US$834 m derived from the MD&A’s accrual capex. A five-year series is not shown because FY2021 quarterly data is incomplete in the sources used; “—” marks unavailable figures rather than mixing bases. Net debt is filed total principal debt less cash. Antero pays no dividend.

The balance sheet did the heavy lifting, then took on the deal. Antero ended 2025 with US$1,404 million of total principal debt — a US$439 million credit-facility drawing, US$365 million of 7.625% senior notes due 2029 and US$600 million of 5.375% notes due 2030, having fully retired its 8.375% 2026 notes — against US$210 million of cash, for net debt of about US$1.19 billion. It then funded the HG acquisition: long-term debt rose to US$2.66 billion at 31 March 2026 via a new US$1.50 billion term loan and US$750 million of 2036 notes. The deleveraging since has been fast: the company generated over US$750 million of free cash flow from December through the end of Q1, repaying over a quarter of the acquisition cost, and with the Utica proceeds has funded more than half of it — guiding to 1× leverage by mid-2026, six months ahead of its prior expectation. Antero has carried an investment-grade rating from Fitch since September 2022 and from S&P (BBB−) since May 2024, which it expects to keep reducing the letters of credit tied to its firm-transportation portfolio.

The obligation that is not on the balance sheet is larger than the one that is. At 31 December 2025, Antero’s long-term contractual obligations under agreements with minimum volume commitments totalled US$8.2 billion over the terms of the contracts, with firm transportation agreements expiring between 2027 and 2058 and gathering, processing and compression agreements between 2032 and 2038. These are the flip side of the market access that lets Antero sell into premium Gulf Coast, Midwest and LNG-linked markets — and they are payable on minimum volumes whether or not the wells produce. The company estimates US$0.02 to US$0.05 per mcfe of net marketing cost in 2026 for capacity it cannot fill, which is the visible tip of that commitment.

Hedging: modest, and struck above the market. Unlike its neighbours, Antero entered 2026 with hedges in the money. At 31 December 2025 it held Henry Hub fixed-price swaps on 770,000 MMBtu/d of 2026 production at US$3.90/MMBtu and 330,000 MMBtu/d of 2027 at US$3.98, plus collars on 500,000 MMBtu/d of 2026 with a US$5.83 ceiling, basis swaps on 150,000 MMBtu/d of NYMEX-to-TETCO M2 at a US$0.85 differential, and small option positions tied to its volumetric production payment. Total derivative assets were US$81 million. Against a market near US$3.25 that swap book is a genuine asset — a useful contrast with CNX, whose 2026 book is struck at US$2.74.

Capital returns are buyback-only. Under the US$2.0 billion authorisation put in place in 2022, Antero repurchased approximately 4 million shares for US$136 million in 2025 and has retired 32 million shares in total since inception, with US$914 million of capacity remaining at year-end. There is no dividend.

Figure 5. Total revenue by fiscal year, FY2022–FY2025

Chart source: Table 4, this analysis; Antero Resources FY2025 Form 10-K and stockanalysis.com for FY2022. Free cash flow (US$2,107m → −137 → 133 → 811) and net debt (falling to US$1.19 bn before the HG deal takes it to US$2.66 bn) are read from Table 4 and §3 rather than overlaid as additional series.

4. Management, strategy & corporate structure

4.1 Management & governance

Antero changed chief executives in 2025. Michael N. Kennedy is Chief Executive Officer and President, directing development, marketing and capital allocation; founder Paul Rady transitioned to Chairman Emeritus under an agreement dated August 2025, and Benjamin A. Hardesty serves as Chairman of the Board. Senior technical authority sits with W. Patrick Ash, Senior Vice President — Reserves, Planning and Midstream since June 2019 and previously Vice President — Reservoir Engineering and Planning, who reviews and approves the company’s internally prepared reserve estimates before they go to the independent engineers at DeGolyer and MacNaughton.

The board has seven members — small for a company of this size — with special meetings callable by the chief executive, the chairman or the board. Governance emphasis, as stated in the filing, falls on balance-sheet discipline, reserves governance and oversight of enterprise and commodity-price risk; senior management reviews and approves any significant change to proved reserves quarterly, which is a meaningful control for a company whose principal asset is an estimate.

The governance question a reader should weigh is timing. This is a first-year chief executive executing the largest acquisition in the company’s history, on a seven-person board, in a business whose economics turn on multi-decade midstream contracts. The transition was orderly and Kennedy is a long-serving insider rather than an outside hire, but the HG integration is the test, and it is happening now.

4.2 Strategy & capital allocation

The stated strategy has three legs, and they are unusually consistent with what the company actually did. Expand the long-lived core Marcellus position in West Virginia, which HG delivered. Reduce cash costs and expand margins through incremental dry-gas development and by lowering firm-transportation commitments over time — the single most important sentence in the filing, because it concedes that the transport book is the problem and commits to shrinking it. And maintain a strong balance sheet and a sustainable leverage profile, which the post-deal deleveraging path supports.

The capital-allocation stack for 2026 is concrete: a US$1.1–1.3 billion budget funding 70 to 80 net wells, with up to US$200 million of it explicitly discretionary and contingent on commodity prices; the residual goes to debt reduction until leverage reaches 1×, then to the remaining US$914 million of buyback authorisation. The forward targets are equally specific — 1,497 bcfe of 2026 production and US$0.30/mcfe of corporate cash-cost reduction from HG. There is no dividend and no stated intention to start one.

4.3 Ownership & corporate structure

The defining structural fact — the 29% Antero Midstream stake and the transactions around it — is covered in Section 2.5. What that section does not spell out is the contractual dedication underneath it: all of Antero’s current and future natural gas production in West Virginia, Ohio and Pennsylvania is dedicated to Antero Midstream for gathering and compression, and Antero Midstream holds a right of first offer on processing and fractionation. The relationship is genuinely two-sided — it caps Antero’s ability to shop for cheaper midstream, and it returns roughly a quarter of the toll through the equity stake — and the HG transaction pair extended it onto the new acreage, with US$2.8 billion of upstream going to Antero Resources and US$1.1 billion of midstream to Antero Midstream from the same seller on the same day.

The drilling partnerships leave two visible traces in the accounts: net income attributable to Antero sits below consolidated net income, and the Martica noncontrolling interest holds 38 bcfe of proved reserves and a US$72 million standardized measure of its own.

On the equity side the structure is plain: 309.84 million shares outstanding, no dual class, 3.29% insider ownership against 89.72% institutional, and a share count that has fallen by 32 million since 2022 through the buyback.

5. ESG & sustainability

Antero’s environmental disclosure is unusually quantitative for an Appalachian producer, and it is concentrated where it matters commercially: methane. The company reports a 2024 methane leak-loss rate of 0.010% and has replaced approximately 7,779 natural-gas-driven pneumatic devices since 2021 — the single largest source of routine methane venting in upstream operations — alongside a balanced drill-out technique and vapour-recovery systems across operated assets. It participates in the EPA’s Natural Gas STAR Program, ONE Future and The Environmental Partnership, the three recognised industry frameworks for methane performance.

The commercial logic is explicit and worth stating plainly rather than treating as boilerplate: Antero sells into LNG-linked and international markets through its firm-transportation portfolio, and buyers in those markets increasingly price on certified emissions intensity. A verified leak-loss rate an order of magnitude below the commonly-cited industry thresholds is therefore not only an environmental outcome but a marketability asset — it protects access to precisely the premium markets that justify the transport commitments.

The balanced read: this is a real, measured, externally-benchmarked methane programme with a specific device-replacement count behind it, which places Antero at the better end of its peer set on the one environmental metric that most affects a gas producer’s licence and price realisation. Three caveats keep it from being a clear five-star profile. The disclosed leak-loss rate is a 2024 figure appearing in a 2025 filing, so the most recent year is not yet quantified. The filing reviewed here contains no quantified emissions-reduction target with a baseline year against which progress could be judged. And the fundamental Scope 3 exposure of the product itself is unchanged by any of it.

6. Risks

Table 5. Risk register

Source: Antero Resources FY2025 Form 10-K risk factors, contractual obligations and MD&A; Q1 2026 results for post-close figures. Likelihood and impact are the author’s assessment.

The through-line is that Antero’s biggest risk is a contract, not a rock. Its geology is proven, its inventory is deep, its reserve life is fifteen years and its wells work. What it cannot easily change is a US$8.2 billion stack of minimum volume commitments running to 2058, negotiated in an era when Appalachian producers needed to buy their way out of the basin and priced accordingly. That obligation is why the cost line is what it is, why the fully-loaded margin trails a dry-gas peer despite a 45% higher realised price, and why management’s stated intention to “lower commitments on firm transportation over time” is the most important forward-looking sentence in the filing.

The two risks that would actually break the thesis compound each other: the midstream cost structure and NGL prices. The transport commitments are fixed; the NGL revenue that justifies them is not. In a scenario where C3+ realisations fall toward the mid-US$30s while the commitments stay at US$8.2 billion, Antero’s cash margin compresses far faster than a dry-gas peer’s — the very operating leverage that makes the liquids story attractive on the way up. Which price regime arrives is a macro question rather than a company one; Commodities Across the Cycle sets out the regimes in which energy commodities lead and lag. The offsetting comfort is that the balance sheet risk, which looked material in February, is being retired at speed.

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. Antero realises above the benchmark, not below it: FY2025 booked US$3.56/Mcf against a US$3.38 first-of-month average, so realized gas = Henry Hub plus US$0.18 — the return on the transport it pays for. NGLs and oil are held at their FY2025 realisations. Discount rate 10%, the E&P convention for a single-basin producer and the rate the standardized measure is struck at, sensitised 8–12%. Share price US$39.41 (4 September 2026 close), 307.44 m shares, balance sheet as of 30 June 2026.

Antero is valued on the E&P producer archetype, run as a sum-of-the-parts over five claims, which is more than any other name in this series needs: the proved developed and proved undeveloped reserve tranches, the HG acquisition that closed after the reserve report was struck, the 29% Antero Midstream stake the accounts carry at a twelfth of its market value, and a drilling-inventory row the filing lets us size properly. The method behind the numbers is set out in the How to Value Commodity Stocks guide; this section applies it to Antero. The headline is a deck-to-value map, not a single number: the blended fair value is US$24.28/share at the US$3.00 base price, US$16.06 at US$2.50 and US$33.08 at US$3.50, and each US$0.50/MMBtu of Henry Hub is worth about US$6.1 of NAV/share (US$12.3 per US$1.00) — 21% of NAV per step, the mildest deck leverage in this series, because 39% of the revenue is liquids and a quarter of the value is a listed midstream stake that does not move with gas at all. The tiers frame the structure: the producing base, HG, the midstream stake and the whole bridge are worth US$25.24/share, the booked undeveloped tranche US$2.77 and the unbooked inventory US$1.76. The section sets the current US$39.41 price against that map only in §7.6, where the rating and the flip prices are published.

7.1 Method selection

Antero is a producer, so the blend starts from the E&P-producer default set out in the valuation guide linked above (NAV/DCF 45% / EV/EBITDA 30% / a reserve- or flowing-unit read 25%). The third default method is not carried: the guide’s EV/2P anchor is struck on oil-equivalent barrels, and at a 6:1 conversion it implies US$1.67 per mcfe against the US$0.51 per mcfe Antero’s own audited PV-10 carries — 3.3× the company’s own reserve value, the widest mispricing in this series, because a 61%-gas reserve base measured in barrel-equivalents is exactly what that anchor is not built for. It is set aside, reported unweighted in §7.5, and its absence logged as a data gap. The substitute, in the guide’s order, is a cash-flow read built from disclosed lines — P/CF at the archetype’s own 4.5× anchor, rather than a free-cash-flow yield, because the guide publishes a P/CF anchor for this archetype and no yield anchor. That puts two methods in the cash-flow family, so they are held together at the 50% collinear ceiling and the NAV takes 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 per Section 1; target multiples derived in §7.3 from the archetype anchors, not from the Section 2.7 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% — the HG mark is a bridge input to the intrinsic method, not a comparables method.

7.2 Net asset value

Vehicle map. Antero’s structure is the most layered in this series, and two of its four layers are invisible in the balance sheet at anything near their value.

Table 7. Vehicle map

Source: this analysis; acreage, reserves, locations, the HG and Utica terms, the Antero Midstream interest and the lease balances per the Antero Resources FY2025 Form 10-K , Item 2 (properties and reserves), the consolidated balance sheets and Note 20 (supplemental oil and gas disclosures); Antero Midstream’s share price and count per stockanalysis.com , 4 Sep 2026 close.

Tax basis, overhead and abandonment. The reserve base is carried at the SEC after-tax standardized measure, so tax is inside the figure by construction — the filing computes it after the effects of available loss carryforwards and minimum-tax credits — and the balance sheet’s US$907 m deferred tax liability sits behind it. An incremental dollar of gas price is taxed at the 23.6% combined statutory rate (21.0% federal plus 2.6% state net of federal, per the FY2025 rate reconciliation), which is the rate the deck adjustment uses. Abandonment is inside the rows: the filing’s own definition of PV-10 is net of “production, future development and abandonment costs”. Corporate overhead is not, and the same definition says so — PV-10 is struck “without giving effect to non-property-related expenses” — so US$171.7 m of cash general and administrative expense is capitalised in the bridge at US$1,005 m, the one place in this series where the filing settles the question outright.

Stage risk (n/a). No asset in the model is pre-production. The proved undeveloped tranche is a booked SEC reserve category and the US$2,560 m of future development costs that convert it are already charged inside the standardized measure, so it takes a 1.00 risk weight. The unbooked inventory row carries its own conversion factor, derived in note 5 below rather than taken as a stage haircut.

The per-asset NPV build. Every NPV the model carries is built here first, one block per claim, so the arithmetic arrives before the answer. The two reserve blocks are Antero’s own disclosed figures apportioned on the filing’s own lines; HG is at its transaction price and Antero Midstream at market; only the inventory factor is an author term, and it is printed as its two components.

Table 8. Per-asset NPV build — base case (US$3.00/MMBtu Henry Hub ≈ US$3.18/Mcf realized, 10%)

Notes to Table 8

1. The filing publishes the standardized measure in total only, and reserve volumes by category, so the after-tax figure is apportioned on the volume split with all of the development capital charged to the undeveloped tranche. Because the undeveloped volumes produce later, the split overstates the undeveloped tier and understates the developed tier while leaving the total unaffected.
2. Cross-check on the pre-tax step, before the Utica adjustment: 19,157 + 3,621 = US$22,778 m, the filing’s own pre-tax future net cash flows.
3. The same ratio implies a flat-equivalent life of 19.5 years for re-discounting — the annuity that reproduces 0.4323 at 10% — and that is the profile the rate rows of Figure 8 move both blocks on.
4. The deck term: 11,770 Bcf of gas reserves × (1 − 3.26% production and ad valorem taxes, FY2025’s US$163 m against US$5,010 m of hydrocarbon revenue) × (1 − 23.6% combined statutory tax) × 0.4323 gives US$3,761 m per US$1.00/MMBtu. The benchmark is taken at US$3.38: Antero’s 2024 SEC gas price of US$2.12 sat within a cent of the industry’s US$2.13 first-of-month average, so its 2025 price tracks the US$3.387 the same average produced. Cross-check against the filing’s own history — the standardized measure moved from US$3,495 m at a US$2.96/mcfe blended price to US$8,110 m at US$3.75, which on the 61% gas share of reserve volume implies US$3,593 m per US$1.00 of gas, 4.7% below the model.
5. The Utica carried ~600 Bcfe of the 19,149 Bcfe booked at 31 December 2025 and was sold for US$800 m — against the US$209 m of SEC-basis value this row removes. On the audited measure the sale created about US$591 m of value; the proceeds are inside the net debt the bridge charges.
6. HG’s reserves are not separately disclosed and the FY2025 filing gives effect to neither transaction, so the acquisition enters at the price paid rather than at a reserve value. Its production is inside the FY2026 guidance the relative methods run on.
7. The equity-method carrying value of US$246 m is an accounting artefact of the 2019 simplification, not a valuation. At market the stake is US$10.12 a share, 26% of Antero’s market capitalisation. Carried at book instead, NAV/share would be US$20.45.
8. Both terms are filed quantities: 4,671 Bcfe of proved undeveloped reserves and 296 proved undeveloped locations. The resulting 15.8 Bcfe per location is the company’s own booked recovery, applied to its own probable-and-possible count.
9. Timing 0.24 — the locations produce after the 15.2-year proved plan, discounted at 10% — multiplied by a conversion factor of 0.42, above the middle of the band for resource beyond the plan because these are the company’s own probable and possible classifications on 86%-held-by-production acreage with no expiry clock, not raw acreage. At 0.05 the row is worth US$271 m (NAV US$28.89); at 0.20, US$1,083 m (US$31.53).

Source: the Antero Resources 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 or read from the market, Derived the arithmetic of rows above it, Estimate the author’s judgement, 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) = [8,110 + 3,761 × (HH − 3.38)] × AF(r, 19.5) ÷ AF(10%, 19.5) × 0.9687.

Table 9. Per-asset model — base case (US$3.00/MMBtu Henry Hub ≈ US$3.18/Mcf realized, 10%)

Source: this analysis, from the Antero Resources FY2025 Form 10-K (Item 2 reserves, locations and transactions, Note 20 supplemental disclosures) and the FY2026 guidance. Every NPV in the last column reproduces from its block in Table 8. One discount-rate treatment: the two reserve blocks and the inventory row that follows them re-discount on the Note 20 timing; the HG mark and the Antero Midstream stake do not, 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 lease, derivative, working-capital, noncontrolling-interest, VPP and debt lines per the Antero Resources FY2025 Form 10-K consolidated balance sheets (p.F-4), Note 12 and Note 20; total debt, 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$25.24 + development US$2.77 + resource US$1.76 = US$29.77 on unrounded inputs — and the producing tier alone sits 36% below the US$39.41 price. Values computed on unrounded inputs, printed to whole US$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$9,153 m equates to US$29.77 per share; the producing tier alone is US$25.24. “Proved reserves” groups the developed (5,621) and undeveloped (851) tranches after the Utica removal; “Inventory & hedges” groups the risked inventory row (541) and the re-marked hedge book (167); “NCI & wkg cap.” groups the Martica minority (−72) and net working capital (−369).

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

		Henry Hub price (US$/MMBtu)
		$2.00	$2.50	Base$3.00	$3.50	$4.00
Discount rate	8%	US$18.59	US$25.70	US$32.80	US$39.90	US$47.01
	10% (base)	US$17.50	US$23.64	US$29.77	US$35.91	US$42.04
	12%	US$16.64	US$22.00	US$27.35	US$32.71	US$38.06

Notes to Figure 8

1. Checksum — the bear column (US$2.50) at the 10% base rate: proved developed = (6,821 + 2,680 × (2.50 − 3.38)) × 0.9687 = US$4,323 m; proved undeveloped = (1,289 + 1,081 × (2.50 − 3.38)) × 0.9687 = US$328 m; + HG 2,800 + Antero Midstream 3,111 + inventory 389 = US$10,950 m enterprise; − 2,491 + 254 − 72 − 1,005 − 369 = US$7,267 m ÷ 307.44 m = US$23.64.
2. Rate rows — they move the two reserve blocks and the inventory row that follows them, on the 19.5-year flat-equivalent profile the standardized measure’s own discount ratio implies (×1.171 at 8%, ×0.866 at 12%), and the capitalised G&A with them. The HG transaction mark, the Antero Midstream stake and every balance-sheet claim are held down each column, which is why the rate axis moves this NAV less than any other in the series.
3. Cost — a +10% shock to the US$2.38/mcfe of lease-operating and midstream cost (US$356 m/yr) takes NAV/share to US$22.29 (−25.1%), the sharpest cost sensitivity in this series and the direct consequence of a US$2.27/mcfe transport bill; a +10% Henry Hub move to US$3.30 lifts it to US$33.45 (+12.4%), and with a 5% cost lag, US$29.71 (−0.2%) — cost inflation eats the whole of a 10% price rise.
4. FX — n/a, Antero reports and trades in US dollars.
5. Stage risk — n/a, no asset in the model is pre-production; the inventory row’s 0.10 factor is a conversion term, sensitised in Table 8’s note 9 rather than as a stage band.
6. Schedule slip — n/a, no development asset stands outside the reserve report’s own five-year 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$6.13, or ~21%; the deck sensitivity is tabulated in Table 11.

Deck sensitivity — what one US$0.50 step of Henry Hub is worth. The grid above holds the recomputed values at each grid price; this table names the slope between them. Antero’s NAV moves less per step, in percentage terms, than any other name in this series — two of its five asset rows do not move with gas at all, and the hedge book moves against the deck.

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; the hedge and free-cash-flow rows carry no percentage because their base values sit near or cross zero. Linear over is the Henry Hub range on which the slope holds: ¹ the hedge book is linear because the disclosed instruments are swaps, and it crosses from asset to liability at about US$3.95; ² below ~US$2.43 the cash-tax line reaches zero and both cash-flow slopes flatten, and FCF/share crosses zero at ~US$2.86; ³ the ladder blend steps 6.57 → 8.22 → 8.80 → 9.98 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$466 m per step (963 Bcf of gas volume, net of production taxes) and cash flow per share US$1.16. How to use it: start from the base-price values (NAV/share US$29.77, blended fair value US$24.28) 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$32.8 and a held-multiple blend of ~US$27.2; for a reading that also lets the multiples move with the cycle, use the ladder columns of Table 18.

P/NAV ladder (unweighted). The NAV restated as a price map, straight 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, the base rate held. Read down a column for the deck you hold, across a row for the multiple you would pay; where today’s quote sits on the map is said once, by the market-implied deck in §7.5.

Table 12. P/NAV ladder — 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 (17.50 / 23.64 / 29.77 / 35.91 / 42.04) × 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; Antero’s 0.82× target, derived in §7.3, reads US$24.41 at the base price, US$19.38 at US$2.50 and US$29.44 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 — parity at the base price is US$29.77, and this is the flattest map in the series, because two of the five asset rows are fixed marks.

7.3 Relative valuation

At US$39.41 and 307.44 million shares, Antero’s market capitalisation is ~US$12.12 billion and enterprise value ~US$14.61 billion on the filed debt basis. This section values Antero 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 Antero against EQT, Expand, 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 along the ladder.

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. The line nets to almost nothing, and the composition is the point: the heaviest positive in this series on reserves sits against the heaviest negative on cost, and they very nearly cancel. The one line is applied, unchanged, to every anchor:

Target P/NAV = 0.80× anchor × 1.02 = 0.816 → 0.82× · Target EV/EBITDA = 5.0× anchor × 1.02 = 5.100 → 5.1× · Target P/CF = 4.5× anchor × 1.02 = 4.590 → 4.6×. 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, unit costs and the capital budget per the Antero Resources FY2025 Form 10-K and the FY2026 guidance. “Forward” is the next twelve months = the FY2026 guidance year; the volume ties to guidance with nothing added above it, and the guided US$0.30/mcfe cost reduction is deliberately excluded — it is a synergy target, not a guided unit cost, and it is reported unweighted in §7.5 instead. Reconciliation: run at the reserve report’s own US$3.38 benchmark this build gives US$1,933 m, or US$1.292/mcfe, against FY2025’s actual US$1,619 m on US$1.289/mcfe — a 0.2% difference, so the forward build reproduces the company’s reported margin on 19% more volume. Cost-basis note: the NAV rows use the reserve report’s own US$2.43/mcfe of future production costs; this build states the cash lines 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, and adds back the Antero Midstream stake, whose earnings are equity-accounted and therefore sit outside consolidated EBITDA — a multiple struck on EBITDA alone would value 26% of the market capitalisation at zero. Abandonment is not deducted separately because the reserve report’s costs and the EBITDA line both carry it inside the operating cost stack. 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 land within US$2.91 of each other — the tightest agreement in this series — and that is worth noticing rather than passing over. It happens because the two methods, unusually, see almost the same company: the NAV carries the midstream stake at market and the multiple adds it back, and the reserve base is short enough at 15.2 years that a 5.1× multiple on the guidance year reaches most of it. What the multiple still cannot see is the US$2.6 billion of future development capital and the unbooked inventory, and those roughly offset. The gap that matters at Antero is not between the two methods; it is between both of them and the price.

7.4 Further weighted methods — P/CF support

The third weighted read is a cash-flow multiple on Antero’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 expense, depletion, the tax reconciliation and the capital budget per the Antero Resources FY2025 Form 10-K consolidated statements of operations, Note 13 and Item 2; the 31 March 2026 debt figure per the Q1 2026 results. Every trailing line sits on FY2025, the latest reported fiscal year. Free cash flow of US$96 m at the base deck is the arithmetic of a company spending US$1.2 bn to lift volumes 19% — it is a build year, not a run rate, and free cash flow turns negative below ~US$2.86/MMBtu.

The method lands at US$19.40, the lowest of the three, and the reason is the capital and the interest rather than the margin: this is the only read that charges a full year of post-acquisition interest against a cash-flow line that has not yet had the guided cost reduction in it. Both cash-flow reads are two views of one signal rather than two confirmations, which is what the collinear cap exists to contain — the family carries 50% between them, not 50% each.

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, PV-10, hedge, transaction and cost figures per the Antero Resources FY2025 Form 10-K (Item 2, Note 12 and Note 20); Henry Hub history per the U.S. EIA monthly series, five-year window September 2021–August 2026; the trailing multiple series, consensus and analyst count per stockanalysis.com , read 6 Sep 2026 on the 4 Sep close. Antero pays no dividend, so no yield-support price is computable.

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 whole section reads on one price axis. Each column is its own world, and Table 18 lists what changes in it 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 the deck; the discount rate steps out to 12% and 14% on the downside and holds at the 10% convention on the upside. The hedge book is re-marked in every column from its disclosed strikes; the HG mark and the midstream stake are held. The last memo row is the same blend with the multiples held at their targets, which is the linear version a reader can reproduce 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 × 24.41 + 0.30 × 27.32 + 0.20 × 19.40 = 12.21 + 8.20 + 3.88 = US$24.28 (on unrounded values, 24.281). Inputs behind the rows, by column: the flexed targets 0.656× · 4.08× · 3.68× / 0.738× · 4.59× · 4.14× / 0.82× · 5.1× · 4.6× / 0.902× · 5.61× · 5.06× / 0.984× · 6.12× · 5.52×; forward EBITDA US$648 m / 1,114 m / 1,579 m / 2,045 m / 2,511 m; cash flow per share US$1.59 / 3.06 / 4.22 / 5.37 / 6.53; cash tax US$0 m / 15 m / 124 m / 234 m / 344 m — it reaches zero below US$2.43; the hedge book re-marked at +US$342 m / +US$254 m / +US$167 m / +US$79 m / −US$9 m from the disclosed strikes. The HG transaction mark (US$2,800 m) and the Antero Midstream stake (US$3,111 m) are held in every column — a price paid and a listed quote carry no gas-deck exposure. Risk weights are 1.00 in every column except the inventory row, held at 0.10. No method returns negative equity in any column, so nothing is floored. The guided US$0.30/mcfe cost synergy is not in any cell — with it, the base blend is US$27.54 (§7.5). Illustrative scenarios, not forecasts.

Figure 9. Value per share by method and scenario

		Scenario (Henry Hub deck)
		Deep Bear$2.00	Bear$2.50	Base$3.00	Bull$3.50	Deep Bull$4.00
Method	SOTP NAV × P/NAV (50%)	US$10.46(−57%)	US$16.23(−34%)	US$24.41(base)	US$32.39(+33%)	US$41.37(+69%)
	EV/EBITDA (30%)	US$10.29(−62%)	US$18.03(−34%)	US$27.32(base)	US$38.16(+40%)	US$50.54(+85%)
	P/CF (20%)	US$5.86(−70%)	US$12.66(−35%)	US$19.40(base)	US$27.19(+40%)	US$36.06(+86%)
	Blended fair value	US$9.49(−61%)	US$16.06(−34%)	US$24.28(base)	US$33.08(+36%)	US$43.06(+77%)

Source: Table 18; each cell recomputed at its column’s deck, rate, hedge mark and multiple flex, never scaled; data-level ranked 0–9 across the whole grid. The three methods sit closer together here than anywhere else in this series, and the fan is narrow on both sides — the consequence of two fixed asset marks, a hedge book that works against the deck, and a reserve life short enough that a cash-flow multiple reaches most of it. Current share price US$39.41 (4 Sep 2026); market-implied deck ~US$4.30/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$24.28, inside a US$9.49 (Deep Bear, US$2.00) – US$43.06 (Deep Bull, US$4.00) range, against a US$39.41 price — an implied −38.4%, Overvalued, published as Overvalued “(wide band)” because the deep-bear blend sits 76% below the price. At the base price the guidance-year free cash flow of US$96 m is a 0.8% yield on the US$12.12 bn market capitalisation — the arithmetic of spending US$1.2 billion to lift volumes 19%, not a run rate. Rating-flip prices: with the multiples held at their targets, the base blend crosses up into Modestly overvalued above ~US$3.28/MMBtu Henry Hub (+9% from the base price) and into Fairly valued above ~US$3.96 (+32%); Overvalued is the bottom band, so no downward flip exists. The one assumption that drives the downside is Henry Hub at the US$2.00–2.50 grid prices against a US$2.27/mcfe toll that has risen every year since 2023 — though the hedge book, worth +US$342 m at US$2.00, and the midstream stake, worth US$10.12 a share whatever gas does, are both real cushions in that world.

The three methods land within US$7.92 of each other, the tightest cluster in this series, and that agreement is what makes the read hard to argue with: there is no method here that gets to the price. What separates Antero from the rest of the basin is composition rather than level. A quarter of the market capitalisation is a listed midstream stake the accounts carry at a twelfth of its value; another US$2.8 billion is an acquisition that closed after the reserve report was written; and the audited reserves themselves are worth US$0.51 per mcfe, the lowest in this series — not because the gas is poor but because 60% of the revenue leaves before it reaches the equity. The producing tier plus the whole bridge is worth US$25.24/share and the booked undeveloped tranche US$2.77 more; a buyer at US$39.41 is paying a US$10 premium to the sum of everything above for Henry Hub at about US$4.30 held flat. The one thing that would change the arithmetic materially is the company’s own: deliver the guided US$0.30/mcfe of HG cost synergy and the blend moves to US$27.54, the implied return to −30.1%, and the market-implied deck down to ~US$4.02 — worth almost exactly one rating band, and a third of the gap. That is the whole investment question, and it is a cost question rather than a gas question. The Street’s US$49.65 target underwrites the synergy in full and a higher deck besides. 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, noncontrolling-interest and VPP 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. Realized gas = Henry Hub plus US$0.18, the FY2025 premium to the first-of-month benchmark; NGLs and oil held at FY2025 realisations. Discount rate 10% — the E&P convention for a single-basin producer, and the rate the standardized measure is struck at — sensitised 8–12% on the two reserve blocks, the inventory row and the capitalised overhead; the HG mark and the Antero Midstream stake do not re-discount; no jurisdiction premium (Dim 8 ★★★★★, 100% United States, so the band is +0%). Share basis 307.44 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 on the ladder; 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 (×1.02); metric basis forward FY2026 (guidance year); EBITDA before all capital and after G&A, unhedged and before the guided synergy; net debt excludes the US$2,128 m of capitalised operating leases, which are charged inside the cost rows; 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: Antero’s own disclosed after-tax standardized measure, apportioned to the proved developed and undeveloped tranches on the filing’s own inflow, production-cost and development-cost lines, moved to the deck on a term built from the filing’s own gas volumes, production-tax ratio, tax reconciliation and discount ratio — calibrated within 4.7% of the company’s own 2024-to-2025 standardized-measure history — and reduced 3.13% for the Utica divestiture; HG at its US$2.8 bn transaction price; Antero Midstream at the 4 September market close; the inventory row on the filing’s own location counts at a 0.10 conversion factor. Tax basis the SEC schedule (basis 3); abandonment inside the reserve report, corporate overhead outside it and capitalised in the bridge, both per the filing’s own PV-10 definition. Primary value yardstick P/NAV (equity form). Stage-risk placement n/a — no pre-production asset. Known data gaps: (1) HG’s reserves are not separately disclosed and the FY2025 reserve report predates the acquisition — the asset is held at the price paid and does not move with the price grid, which understates gas leverage; closed by the FY2026 reserve report; (2) the standardized measure by reserve category n/d — apportioned on the filed volume and cost lines, which overstates the undeveloped tier and understates the developed tier without changing the total; (3) the Utica’s share of the standardized measure n/d — removed pro rata on volume, which likely removes more value than it should since Ohio is drier than the West Virginia liquids window; (4) post-acquisition cash interest n/d — the FY2025 charge is scaled by the debt increase, and the true figure depends on the term loan and 2036-note coupons; (5) a gas-basis EV/reserve anchor n/d — the asset-family method is not carried (§7.1). None changes the rating; the guided cost synergy, which is disclosed but not a cost, would move it one band and is reported in §7.5. 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)

Antero’s forward catalysts are unusually concrete because most of them are the mechanical consequences of a deal that has already closed.

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

Source: Antero Resources FY2025 Form 10-K (hedge book, MVC expiries, buyback capacity, the Antero Midstream interest), the Q1 and Q2 2026 results (synergy guidance, production guidance, leverage target) and the U.S. EIA Short-Term Energy Outlook . Synergy and stake values per Section 7. Timing reflects company guidance and is not guaranteed.

The common thread is that the transformation is already paid for — the acquisition closed, the divestiture funded much of it, and the remaining work is operational. The swing factor is not access to capital or to acreage; it is whether a first-year chief executive extracts the cost synergy he has publicly guided to, in a business where the cost line has moved the wrong way for three consecutive years.

9. Rating & verdict

Antero 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 Appalachian peer set declared in Section 2.7 and substantiated below.

Table 20. The Antero Resources scorecard

The composite is the weighted average of the nine stars above: 0.15 × (4 + 2 + 5 + 3 + 4) + 0.0625 × (4 + 3 + 5 + 4) = 2.70 + 1.00 = 3.70/5 → ★★★½, Solid.

Source: the Metal Pilot Company Scorecard; evidence in Sections 2–7. Peer basis: the Appalachian gas producers named in Section 2.7 (EQT, Expand Energy, Range Resources, CNX). Rows are ordered by weight, descending, with the composite last.

The two-axis verdict. Quality Solid (★★★½, 3.7/5) × Value Overvalued (wide band) → the HG synergy is worth about one rating band, and the price already assumes more than that. The quality axis is genuinely bimodal, and that shape is the finding. Two dimensions score ★★★★★ — the reserve base and the jurisdiction — and one scores ★★☆☆☆. Antero owns the best combination of reserve life and product mix in Appalachia and runs it through the most expensive midstream contract stack in Appalachia. Those are not independent facts: the liquids that make the reserves valuable are the same molecules that require processing, fractionation and long-haul transport to reach a market. The company did not make a mistake so much as make a trade, and the trade is currently marginally against it.

The value axis has moved, and the composition is what matters. At US$39.41 the shares sit 1.32× a US$29.77 net asset value built from the company’s own after-tax standardized measure at a US$3.00 deck, with the HG acquisition at the price paid and the Antero Midstream stake at market; the blended fair value of US$24.28 implies −38.4% (Section 7.6). A third of that net asset value is the midstream stake — worth US$10.12 a share at market against US$0.80 in the accounts — rather than proved reserves, and the reserves themselves are worth US$0.51 per mcfe, the lowest in this series, because 60% of the revenue leaves in gathering, processing and transport before it reaches the equity. What tips the verdict from bear to bull is the cost line, and it is quantifiable: deliver the guided US$0.30/mcfe and forward EBITDA rises US$449 million, the blend moves to US$27.54 and the implied return to −30.1% — worth almost exactly one rating band, and about a third of the gap to the price. Fail to deliver it, and an investor has paid a US$10 premium to the sum of every asset the filing discloses, for a business whose costs have risen three years running while carrying US$8.2 billion of obligations to 2058. The Street’s US$49.65 target underwrites the synergy in full and a higher gas deck besides. 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, production, realized prices, unit costs, acreage, hedge positions, contractual obligations, structure, management and risk factors are from Antero Resources Corporation — 10-K Filing / Annual Report — 2025 (fiscal year ended 31 December 2025), including its Production, Price and Cost History and acreage tables, the Acquisitions and Divestitures disclosure, the long-term debt and derivative notes, and the supplemental oil and gas disclosures with reserves audited by DeGolyer and MacNaughton and internally approved by W. Patrick Ash, Senior Vice President — Reserves, Planning and Midstream. Reserves are SEC-basis proved reserves net of royalty at 31 December 2025, calculated assuming partial ethane recovery with rejection of the remaining ethane using the unweighted twelve-month average first-day-of-the-month prices; PV-10 is the company’s disclosed non-GAAP pre-tax measure and the standardized measure its GAAP after-tax equivalent. Post-year-end developments — the HG Acquisition and Utica Shale Divestiture closing on 3 February 2026, Q1 2026 results, the US$0.30/mcfe synergy guidance, the 1,497 bcfe production guidance and the 1× leverage target — are from the company’s Q1 2026 results (30 April 2026) and the related 10-Q. The investment-grade ratings are per S&P Global Ratings (BBB−, May 2024) and Fitch (since September 2022).

Market data (share price US$39.41 at the 4 September 2026 close, 307.44 million shares, market capitalisation ~US$12.12 billion, and the five-year trailing multiple series used as a cross-check in Section 7.5), the four-year financial history and the 20-analyst Buy consensus with its US$49.65 target are from stockanalysis.com , sourced from S&P Global Market Intelligence and Fiscal.ai, read on 6 September 2026; the Antero Midstream share price of US$22.60 and 474.67 million shares are at the same close. One source conflict is resolved explicitly and quantified in Section 7.2: providers report Antero’s total debt at US$4.62 billion, materially above the filed principal debt, by capitalising the US$2.13 billion of firm-transport and gathering lease liabilities. Those payments are already inside the US$2.27/mcfe cost line and the reserve report’s production costs, so this analysis deducts them once, in the cost rows, and uses net debt of US$2.49 billion — the difference is the whole of the gap between the enterprise value quoted here and the one a screen will show. The Henry Hub trailing averages behind the price deck — 3-month US$2.94, 6-month US$2.93, 12-month US$3.59, and the five-year average of US$3.74 for September 2021–August 2026 — are from the U.S. EIA monthly spot series; the 2027 forecast used 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 company’s disclosed after-tax standardized measure of US$8,110 million — not the pre-tax PV-10 — apportions it to the proved developed and proved undeveloped tranches on the filing’s own inflow, production-cost and development-cost lines, moves it to the base deck on a term built from the filing’s own gas volumes, production-tax ratio, tax reconciliation and discount ratio, removes the divested Utica at its 3.13% volume share, and then adds the HG assets at the US$2.8 billion paid for them and the listed Antero Midstream stake at its 4 September market close. That deck term reconciles within 4.7% of the company’s own 2024-to-2025 standardized-measure history, and the forward EBITDA build run at the reserve report’s own benchmark lands within 0.2% of FY2025’s reported margin on 19% more volume. Corporate overhead is capitalised in the bridge because the filing’s own PV-10 definition excludes non-property expenses, and abandonment is not, because the same definition includes it — the one filing in this series that settles both questions outright. The guided US$0.30/mcfe HG cost synergy is deliberately excluded from the build and reported unweighted instead; it is worth US$449 million a year and about one rating band. The remaining author judgement is the 0.10 conversion factor on the 983 probable-and-possible drilling locations, sensitised in Section 7.2. Two sanctioned template adaptations are noted. First, because Antero operates a single basin, the standard by-asset revenue split is replaced by a per-mcfe unit-economics figure (Figure 3), which is the more informative cut for this company. Second, the asset-map figure is omitted — a proportional-symbol map of the Appalachian footprint would not render legibly at this scale, so Table 2 and the §2.1 prose carry the acreage picture instead; every published figure is an inline HTML/CSS component. 9 September 2026 — re-rating and vintage alignment, no valuation figure moved: the composite is stated as 3.7/5 (★★★½), the weighted average the nine published stars produce (0.15 × 18 + 0.0625 × 16 = 3.70), which the title, the Section 1 tile and the verdict had carried as 3.8; the weighted arithmetic is now printed beneath the scorecard; the band is unchanged at Solid; the front-matter date is set to the analysis as-of date. Data as of 6 September 2026; refreshed on each annual report and on material events. Provenance: Antero Resources 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. Reserve and PV-10 figures are estimates 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 Antero’s filings, the U.S. EIA and market data and reviewed, but readers should verify before acting. The author holds no position in Antero Resources as of the date of writing.