Devon Energy (DVN) — Stock Analysis 2026 [4.1]

Analysis as of 12 August 2026. This is a point-in-time snapshot of the combined Devon Energy — the all-stock merger of equals with Coterra Energy (agreed 1 Feb 2026, closed ~7 May 2026), which reported its first combined quarter on 4 August 2026. Operating fundamentals (production, reserves, standardized measure) remain on the pro-forma FY2025 / year-end-2025 basis from the Devon/Coterra joint proxy statement, refined by the combined company’s first results; per-basin detail is from Devon’s FY2025 10-K. Market data — share price, market cap, enterprise value, net debt and analyst targets — is as of the 11 August 2026 close. Rating: ★★★★, Solid — Fairly valued (wide band) → the merger re-rating has unwound: a top-tier operator now trading near a conservative fair value, with oil-price and synergy capture the upside. Price deck (Table 3b oil rungs): bear WTI US$60/bbl, base US$70/bbl, bull US$90/bbl; Henry Hub base ~US$3.50/MMBtu; spot WTI ~US$78/bbl and Henry Hub ~US$2.66 as the run-rate cross-check; ~10% discount rate. For information only, prepared with AI assistance — see the disclaimer at the end.

Devon Energy has become one of the largest independents in US shale. Its all-stock merger of equals with Coterra Energy — closed in May 2026 — pairs Devon’s oil-rich, four-basin base with Coterra’s premier Marcellus gas position, creating a ~1.6-million-barrel-of-oil-equivalent-per-day producer with a strong balance sheet, US$1 billion of targeted synergies and a bigger, more diversified reserve base. The thesis in one line: a top-tier, oil-and-gas-balanced US independent with low leverage and enhanced cash returns — one that gave back the merger re-rating over the summer (the shares are down ~13% from their spring high, near US$45) even as oil firmed to ~US$78, leaving it near a conservative fair value with modest upside. To screen the merged Devon against every US upstream name on production, cost, reserve life and free-cash-flow yield, go to Metal Pilot.

1. Snapshot & thesis

The combined Devon Energy Corporation (NYSE: DVN) is an independent oil & natural-gas exploration and production (E&P) company — now headquartered in Houston, Texas following the merger — operating entirely onshore in the United States. It is a producer/operator by archetype and an energy producer by sector, and after the Coterra combination it spans five core areas: the Delaware Basin (the oil-rich Permian core, from both companies), the Marcellus Shale in Pennsylvania (Coterra’s premier natural-gas position), the Rockies/Williston and Eagle Ford (Devon’s oil plays) and the Anadarko Basin (gas, from both). On a pro-forma FY2025 basis it produced ~1,624 thousand barrels of oil equivalent per day (MBOE/d), i.e. ~1.62 MMBOE/d — 34% crude oil, 45% gas, 21% NGL — and held 4,993 million BOE (MMBOE) of proved reserves. (BOE = barrel of oil equivalent, gas converted to oil at 6:1 by energy content; MMBOE = million BOE and MBOE/d = thousand BOE per day, an annual-average daily rate.)

Figure 1. Devon Energy (combined) in numbers

Figure data: Devon/Coterra joint proxy statement pro-forma combined figures; Devon FY2025 10-K ; market data per stockanalysis.com as of the 11 August 2026 close (combined share count ~1,150 m). FCF is a pro-forma run-rate estimate (trailing FCF is depressed by merger-year capex). Rating per Section 9.

Table 1. Devon Energy (combined, pro-forma FY2025) in numbers

Source: Devon/Coterra joint proxy statement , unaudited pro-forma combined financial statements and reserve disclosures (as if the merger completed 1 Jan 2025); Devon FY2025 10-K ; market data per stockanalysis.com , 11 Aug 2026. EV = market cap + net debt (total debt ~US$11.9 bn − cash ~US$1.0 bn = ~US$10.9 bn); combined run-rate EBITDAX is an estimate (~US$11.5 bn at the base deck). Pro-forma operating figures are illustrative, not the combined company’s audited results.

Thesis in brief. Bull: the merger creates a top-tier US independent (~1.6 MMBOE/d, ~5.0 Bn BOE proved) that is more diversified (Delaware oil + Marcellus gas), carries low leverage (~1.0× net debt/EBITDAX), targets US$1 billion of annual synergies, and pays a ~2.8%-yield dividend alongside a >US$5 billion buyback — and after a ~13% summer de-rating trades near a conservative net asset value even with oil firm at ~US$78. Bear: it is still a price-taker, now gassier (only 34% oil, more exposed to a Henry Hub tape near US$2.66 and Marcellus basis), it must integrate the largest deal in either company’s history under a first-year Devon CEO and a new Houston headquarters, and the base-case blend sits only ~6% above the price on a conservative deck. What tips it: whether US$1 billion of synergies and continued oil strength lift the free-cash-flow story — versus a soft gas tape and integration friction that leave the enlarged company treading water. 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

The combined company is a leveraged play on North American oil and gas, so the backdrop matters on both sides: after a soft 2025 (WTI realizations near US$63/bbl), crude firmed to ~US$78/bbl by August 2026, while Henry Hub gas stayed weak near US$2.66/MMBtu — the reason Coterra’s low-cost Marcellus volumes are a swing factor for the merged group and a drag while gas is this soft. For the full picture of how crude is priced, see the Oil — A Complete Market Guide ; the gas and NGL side, now a much larger share of the portfolio, is covered in the Natural Gas guide . This section spends its words on the company.

2.1 Portfolio overview & map

The merged portfolio is best understood as an oil engine (Devon) bolted to a gas engine (Coterra), unified in the Delaware Basin where both held premium Permian acreage. Coterra contributes the Marcellus (a top Appalachian gas position), adds scale in the Anadarko, and deepens the Delaware; Devon brings the Rockies/Williston and Eagle Ford oil plays. All operations are 100%-operated onshore US.

Table 2. Combined asset base (pro-forma FY2025)

Source: Devon/Coterra joint proxy statement (Coterra assets: Delaware, Marcellus, Anadarko) and Devon FY2025 10-K (Devon basins). All interests are publicly listed operated positions (NYSE: DVN). Output shares are approximate pending combined-company segment reporting; Devon contributed ~840 MBOE/d and Coterra ~784 MBOE/d of the ~1,624 MBOE/d pro-forma total.

The concentration read shifts with the merger: the Delaware Basin remains the single largest and highest-value area, but the portfolio is now materially more balanced between oil and gas, with the Marcellus turning Devon from a ~46%-oil producer into a ~34%-oil, gas-heavy major. A proportional-symbol asset map is not drawn — a component that prints a value on every mark cannot render a legible geographic map (Section 10.1) — so the table and this paragraph carry the read.

2.2 Revenue split — by product & by asset (rule A11)

Two cuts of the same revenue base tell the story. By product, the combined company is still oil-majority by revenue even though it is gas-majority by volume, because Coterra’s Marcellus gas realizes a low price: of ~US$18.4 billion of pro-forma oil, gas & NGL sales, oil was ~68%, natural gas ~19% and NGLs ~13%. By asset, the Delaware Basin leads, with the Marcellus the largest gas contributor.

Figure 2. Pro-forma FY2025 upstream revenue by product

Figure data: Devon/Coterra joint proxy statement ; combined oil, gas & NGL sales US$18,399 m (Devon US$11,223 m + Coterra US$7,176 m), split by the two companies’ disclosed oil/gas/NGL sales (oil ~US$12.6 bn, gas ~US$3.5 bn, NGL ~US$2.3 bn).

Figure 3. Approximate production by core area (pro-forma FY2025)

Figure data: this analysis, from Devon FY2025 10-K basin volumes and joint proxy Coterra totals; area shares are approximate and combine Devon’s Delaware/Anadarko with Coterra’s, pending combined-company segment reporting.

Read together: the merged company’s cash flow is led by Delaware oil but meaningfully balanced by Marcellus gas — a genuine two-commodity business now, where a gas recovery is real upside rather than a rounding error. For a multi-basin producer there is no royalty or by-product carve-out; the honest picture is a by-area one.

2.3 Delaware Basin — the unified oil core

The Delaware Basin, spanning West Texas and southeastern New Mexico, is the combined company’s engine and its point of overlap: both Devon and Coterra held premium, largely-contiguous acreage in the economic core of the play, and the merger stitches them into the single most valuable position in the portfolio (~35–40% of combined output, and the bulk of oil volumes and field cash margin). Devon’s standalone Delaware ran ~501 MBOE/d in Q1 2026 (60% of legacy Devon) at a US$27.8/BOE field cash margin; Coterra’s adjacent acreage adds scale and, management argues, the clearest source of the US$1 billion synergy target through shared infrastructure, longer laterals and lower drilling-and-completion costs. This is where the merger’s operational logic is strongest, and where the 2026 capital program is concentrated. The key asset-level risk is price and regional gas takeaway (Waha), not geology.

2.4 Marcellus Shale — the gas engine (new)

The Marcellus Shale in Pennsylvania is Coterra’s flagship contribution and the single biggest change to Devon’s risk profile. It is a premier, low-cost Appalachian dry-gas position — the reason Coterra held ~10.5 Tcf of natural-gas reserves and produced ~1.1 Bcf/d of the combined ~1.6 Bcf/d gas total. Marcellus turns Devon from an oil-leveraged Permian name into a genuine oil-and-gas major with a large, long-life, low-decline gas base — attractive if Henry Hub firms (and as US LNG export demand grows), but a drag while Appalachian gas realizes below US$2/Mcf. It also introduces Appalachian basis and takeaway as a new sensitivity and Pennsylvania as a new operating jurisdiction. Because the combined company has not yet reported segment detail, per-well Marcellus economics await its first stand-alone disclosures; the read here is at the reserve and volume level from the proxy.

2.5 Rockies (Williston) & the oil legs

Devon’s Rockies/Williston position (~187 MBOE/d standalone, ~12% of the combined group; oil-weighted, from the 2024 Grayson Mill acquisition) and its high-margin Eagle Ford (~66 MBOE/d, the portfolio’s best per-barrel field cash margin at ~US$40/BOE, with premium Gulf Coast access after the April 2025 BPX Blackhawk acreage split) remain the oilier ballast against the gassier combined mix. Together with the Delaware, these are what keep the merged company ~68% oil by revenue despite being gas-majority by volume. The Anadarko Basin (Oklahoma, gas-weighted, developed partly through Devon’s Dow joint development agreement and now enlarged by Coterra’s Anadarko acreage) rounds out the base as long-dated gas optionality at the lowest per-barrel margin.

2.6 Production, reserves & costs (consolidated)

On a pro-forma FY2025 basis the combined company produced ~1,624 MBOE/d (593 MMBOE for the year) — 34% oil, 45% gas, 21% NGL — nearly double Devon’s standalone ~840 MBOE/d. Proved reserves stood at 4,993 MMBOE (oil 1,346 MMBbls, gas 14,993 Bcf, NGL 1,148 MMBbls), 80% proved-developed — a higher developed share than Devon standalone (76%), reflecting Marcellus’s large developed gas base — implying a proved reserve life of ~8.4 years, modestly better than Devon’s standalone ~7.9 but still the shale reinvestment treadmill. Cost-wise, the two businesses are both low-cost operators (Devon’s field cash margin ~US$25/BOE in FY2025; Coterra a low-cost Marcellus gas producer), and management frames the US$1 billion synergy target as further per-unit cost reduction. The nuance a reader should hold: the merger improves scale, diversification and reserve life, but dilutes oil leverage — the combined barrel is worth less than Devon’s standalone oilier barrel at any given oil price, offset by more gas upside.

Figure 4. Production by company and combined (pro-forma FY2025)

Chart source: Devon/Coterra joint proxy statement ; pro-forma FY2025 production of 593 MMBOE (~1,624 MBOE/d combined; Devon 307 MMBOE / ~840 MBOE/d, Coterra 286 MMBOE / ~784 MBOE/d). Commodity mix shifts gassier post-merger (§2.6) — carried in the prose, not overlaid (rule A13).

2.7 Peer positioning (rule A12)

The combined company’s peer set is the large-cap US independent E&Ps, now including a gas name to reflect the Marcellus: EOG Resources (EOG), ConocoPhillips (COP), Diamondback Energy (FANG), EQT Corporation (EQT) and Occidental Petroleum (OXY). 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 (approximate, mid-2026)

Source: company filings and market data, mid-2026; figures are approximate and should be refreshed at publish — screen the live upstream peer set on Metal Pilot. Net debt/EBITDA(X) on latest reported basis; for a like-for-like Permian pure-play read, the sibling Diamondback (FANG) analysis uses the same nine-dimension scorecard.

Where the combined Devon sits: among the largest US independents by volume, strong on the balance sheet (~1.0× net debt/EBITDAX — low and investment-grade, if no longer the sector’s very lowest after the merger added Coterra’s debt), and more oil-and-gas balanced than any pure-play — but with a gassier mix and shorter oil-reserve life than the oiliest names, and integration still to prove. That profile — top-tier scale and leverage, genuine diversification, a merely-adequate reserve life — is the crux of the scorecard.

3. Financials & balance sheet

Because the merger closed in 2026, there is no multi-year combined earnings history yet; the cleanest read is the pro-forma combination of FY2025 — how the two businesses add up — which the joint proxy provides. On that basis the combined company generated US$24,805 million of revenue and US$3,768 million of net earnings attributable to Devon (US$3.24 diluted EPS on ~1,164 million shares), with a pro-forma EBITDAX of roughly US$12 billion. Free cash flow is not disclosed on a combined basis, but on the components — Devon’s standalone US$3,119 million plus Coterra’s contribution — it is on the order of ~US$5 billion, before the US$1 billion of targeted synergies phase in.

Table 4. Pro-forma combination (FY2025)

Source: Devon/Coterra joint proxy statement , unaudited pro-forma combined statement of operations and reserve disclosures, and both companies’ historical columns. *Each Coterra share converts to 0.70 Devon shares, so Coterra’s ~760 m shares become ~531 m Devon shares; combined weighted-average diluted ~1,164 m. Pro-forma figures assume the merger completed 1 Jan 2025 and are illustrative, not a projection. A multi-year combined series awaits the merged company’s own reporting.

The balance sheet is a genuine strength. At 30 June 2026 the combined company carries ~US$11.9 billion of total debt against ~US$1.0 billion of cash (~US$10.9 billion net), or ~1.0× net debt/EBITDAX — low and comfortably investment-grade among the large independents, though the merger lifted net debt above the pristine pro-forma level as Coterra’s notes consolidated. Devon has moved to refinance/roll Coterra’s notes and maintains ample revolver liquidity. On capital returns, the combined company pays a US$0.32 quarterly dividend (US$1.28 annualised, ~2.8% yield) alongside a share-repurchase authorization exceeding US$5 billion, restoring buybacks that Devon had paused during the merger’s pendency. The stated logic, echoed by both boards, is that the larger, more diversified company should drive higher free cash flow and a lower cost of capital, closing the free-cash-flow-yield discount both names carried to larger peers.

Hedge & treasury posture. Both legacy books carry hedges: Devon had ~30% of 2026 oil and ~35% of 2026 gas hedged (three-way oil collars around a US$59.59 floor / US$71.22 ceiling; Henry Hub gas swaps at US$3.80 plus WAHA basis protection), and Coterra brings its own Appalachian and Anadarko gas hedges. Neither company trades speculatively or applies hedge accounting; the combined book will be managed centrally to protect the dividend and deleveraging path. Post-merger the group’s larger gas weighting makes Henry Hub and regional basis hedging a bigger part of the treasury story than it was for standalone Devon.

Figure 5. Revenue by company and combined (pro-forma FY2025)

Chart source: Devon/Coterra joint proxy statement ; pro-forma combined revenue US$24,805 m (Devon US$17,188 m + Coterra US$7,645 m, less US$28 m reclassifications). Net earnings and EBITDAX are read from Table 4 and §3 rather than overlaid (rule A13).

4. Management, strategy & corporate structure

4.1 Management & governance

The combined company is led by President & CEO Clay M. Gaspar (Devon’s CEO since 2025), with Thomas E. Jorden — Coterra’s chairman and CEO — as non-executive Chair of an 11-person board split six legacy-Devon (including a lead independent director) and five legacy-Coterra directors, Jorden’s chairmanship capped at two years. The executive committee blends both teams: Shannon E. Young III (Coterra’s CFO) becomes EVP & CFO, while Jeffrey L. Ritenour (Devon’s CFO) moves to EVP & Chief Corporate Development Officer; Michael D. DeShazer (Coterra) runs E&P for Anadarko, Eagle Ford, Marcellus & Rockies and John D. Raines (Devon) runs E&P — Permian; Blake A. Sirgo (Coterra) leads Operations, Robert (Trey) F. Lowe III (Devon) is CTO, with Andrea M. Alexander (Coterra) as Chief Administrative Officer and Adam M. Vela (Coterra) as General Counsel. The governance question a reader should weigh is squarely execution: a first-year CEO and a genuinely split leadership team must integrate two large organizations, relocate the headquarters to Houston, and deliver US$1 billion of synergies — all at once. Every seat named here is a documented executive, not a placeholder.

4.2 Strategy & capital allocation

The strategy is continuity plus scale: the same returns-first framework Devon ran standalone — moderate production growth, capital and operational efficiency, a low reinvestment rate to maximize free cash flow, low leverage, and cash returns — applied to a bigger, more diversified base. The near-term operational agenda has two threads: complete Devon’s US$1 billion business-optimization plan (~US$850 million already captured by end-2025) and capture the US$1 billion of merger synergies (shared Delaware infrastructure, lower drilling-and-completion costs, corporate-cost reduction). Capital allocation prioritizes a competitive fixed dividend, debt reduction, and the resumed >US$5 billion buyback, with the 2026 program weighted to the highest-return Delaware core. The explicit financial goal both boards articulated is to lift free cash flow per share and net asset value per share and to compete better for investor capital as a larger company.

4.3 Ownership & corporate structure

The defining structural event is the company as it now stands: the all-stock merger of equals with Coterra Energy, agreed 1 February 2026, approved by both shareholder bases on 4 May 2026 and closed ~7 May 2026, under which Merger Sub merged into Coterra (now a Devon subsidiary) and each Coterra share converted into 0.70 of a Devon share — leaving legacy Devon holders ~54% and Coterra holders ~46% of the combined company, headquartered in Houston and targeting US$1 billion of sustainable annual synergies. The prior building blocks, all now inside the combined entity, are named: Devon’s Grayson Mill (Williston) acquisition (Q3 2024), the 1 April 2025 BPX Energy Eagle Ford acreage exchange, and the 1 August 2025 buy-in of the remaining Cotton Draw Midstream interest (US$260 million); plus Devon’s strategic minority stakes in WaterBridge (14%), Catalyst Midstream (50%) and Fervo Energy (15%). Coterra contributes its Delaware, Marcellus and Anadarko positions and its own note stack, which Devon has moved to roll into the combined capital structure.

5. ESG & sustainability

The combined company inherits Devon’s target-driven environmental framework — GHG and methane-intensity reduction targets from a 2019 baseline, a net-zero Scope 1 & 2 aspiration, ~US$100 million/year of emissions-reduction capital, and a 90%-plus non-freshwater completions goal in the most active Delaware areas — now applied across a larger, gassier asset base. The gas weighting cuts two ways for ESG: Marcellus dry gas is a lower-carbon-intensity barrel than heavy-oil production and positions the company for LNG-linked demand, but it enlarges the methane-management task across Appalachia and the Permian, precisely as the EPA’s OOOOb/OOOOc methane rules and the IRA methane fee tighten. Governance runs through board committees on safety/operations/resources and environmental/public policy, with the merger adding a fresh integration overlay. The honest limitations carry over: the product is hydrocarbons (structural Scope 3 exposure), and Devon entered the merger with several open EPA air-permit notices of violation (legacy WPX operations in New Mexico and Texas, 2020–2024) still to resolve. Presented even-handedly, the ESG read is above the E&P median on ambition and disclosure, with real regulatory exposure now spread across more basins.

6. Risks

Table 5. Risk register

Source: Devon FY2025 10-K and joint proxy statement risk factors; this analysis. Likelihood/impact are the author’s assessment.

The through-line: the merger reduces some risks (scale, diversification, a still-strong balance sheet) while adding the single biggest new one — integration and synergy delivery — and raising gas-price sensitivity. The combined company’s biggest vulnerability is still a sustained fall in commodity prices, now on both oil and gas; its biggest company-specific unknown is whether US$1 billion of synergies actually lands under a new, blended leadership team; and its most structural constraint remains a ~8-year oil-reserve life. None is a solvency risk; they are the ordinary risks of a well-capitalized price-taker in an integration year.

Figure 6. Risk heat-map

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

7. Valuation

Valuation as of 12 August 2026, in US$. Horizon: spot fair value. Deck (Table 3b oil rungs): bear WTI US$60/bbl, base US$70/bbl, bull US$90/bbl; Henry Hub base ~US$3.50/MMBtu; spot WTI ~US$78/bbl and Henry Hub ~US$2.66 carry as the run-rate cross-check. Discount rate ~10% (US shale E&P). Market data: US$45.43 (11 Aug 2026 close), ~1,150 m shares, net debt ~US$10.9 bn.

This section applies the Metal Pilot valuation module for an E&P producer (oil & gas) archetype to the combined company, with each weighted method taken to a value per share (rule V11): a NAV/DCF on the life-of-inventory cash flows (45%), EV/EBITDAX at peer median (30%), and EV per flowing BOE/d (25%), blended per scenario. The headline conclusion: a blended base-case fair value of ~US$48/share against US$45.43 — about +6%, inside a US$30–73 bear-to-bull range → Fairly valued (wide band). The shares gave back the merger re-rating over the summer, so the small premium the stale-price read carried has become a small discount; the wide band is the oil-price leverage the NAV method carries.

7.1 Method selection

The E&P-producer default weight set is used unchanged (NAV/DCF 45% / EV·EBITDAX 30% / EV per flowing BOE/d 25%). Each weighted method emits a value per share; the peer multiples, PV-10 floor and market-implied deck are cross-checks at 0% weight (rule V12).

Table 6. Valuation method selection & weights

Source: this analysis, per the Metal Pilot valuation module (E&P-producer default weights, rule V18). Input-family exposure: intrinsic 45% (single method, within the 55% cap), cash-flow 30%, asset & capacity 25% — no family above 50%. Cross-checks carry 0% weight.

7.2 Net asset value (NAV / DCF)

At the base deck (~US$70/bbl WTI, ~US$3.50 gas, 10% discount), the combined company’s ~US$5 billion of mid-cycle unlevered after-tax free cash flow — held roughly flat over the proved life and developed inventory, then declining — discounts to an enterprise NAV of ~US$70 billion. This sits above the combined SEC standardized measure of US$32,362 million (the after-tax PV-10 of proved reserves at low SEC prices, especially the ~US$1.32/Mcf gas assumption) and adds risked value for undeveloped inventory. Bridging to equity:

Table 7. NAV build-up (base case: ~US$70/bbl WTI, ~US$3.50 gas, 10% discount)

Source: this analysis; combined reserves and standardized measure per Devon/Coterra joint proxy statement ; net debt and share count per stockanalysis.com , 11 Aug 2026. A simplified corporate FCF model; component PVs are illustrative and highly deck-sensitive.

Figure 7. NAV build-up waterfall

Figure data: Table 7, this analysis.

A base-case NAV of ~US$49/share against US$45.43 is modestly above the price — on intrinsic value the shares now trade at ~0.9× NAV, the small discount that opened when the equity de-rated while oil firmed. The answer turns, as ever, on the commodity deck and the discount rate — and now on gas as well as oil.

Table 8. NAV/share sensitivity — WTI × discount rate

Source: this analysis; NAV/share in US$, base-case combined model (gas held at ~US$3.50 base and flexed with oil). Price columns are the fixed WTI grid (US$60–US$100 by US$10; Table 3b of the valuation playbook). A ±US$10/bbl WTI move shifts NAV/share by roughly ±US$14 — the swing that dominates, now partly damped by the gassier mix.

Figure 8. NAV/share sensitivity — WTI × discount rate

Figure data: Table 8, this analysis. Base US$70/bbl at 10% = US$49/share; the US$70 grid column carries the base outline.

7.3 Relative valuation

Both relative methods convert to a value per share (rule V11). At US$45.43 and ~1,150 million shares, market cap is ~US$52.2 billion and enterprise value ~US$63.2 billion (adding ~US$10.9 billion net debt). On ~US$11.5 billion of run-rate EBITDAX that is ~5.5× EV/EBITDAX — squarely the producer peer median, versus Devon’s ~4.3× standalone: the group re-rated into the merger and has since de-rated back toward the middle. EV/EBITDAX method: applying the ~5.5× peer median to run-rate EBITDAX implies an EV of ~US$63.3 billion, less ~US$10.9 billion net debt = ~US$45.5/share — essentially the current price. EV per flowing BOE/d: the group trades at ~US$38,900/BOE/d, below the ~US$42,000 peer median; at that median on ~1.62 MMBOE/d the implied EV is ~US$68.2 billion, or ~US$49.8/share. The run-rate free-cash-flow yield is ~9% (~US$5 billion on ~US$52.2 billion market cap), above peers — though trailing FCF is temporarily depressed by merger-year capex.

Table 9. Relative valuation vs. the peer set (approximate, mid-2026)

Source: company filings and market data as of mid-2026 (Devon per stockanalysis.com , 11 Aug 2026); peer multiples are approximate. EV/EBITDA(X) and P/CF on latest reported basis; FCF yield on market cap (Devon’s on the pro-forma run-rate, not the depressed trailing figure).

7.4 Cross-checks

These carry no weight in the blend (rule V12); they test whether the model or the market is wrong. PV-10: the combined SEC standardized measure of US$32,362 million (~US$28/share of after-tax proved value at low SEC prices) is a conservative floor the base-deck NAV sensibly exceeds. Analyst consensus: the street sits at US$59.69 (Strong Buy, 27 analysts), about +31% above the price — well above this analysis’ ~US$48 base blend, implying the street capitalises near-strip oil (~US$78) and full synergy capture, where this model uses a conservative US$70 deck. Market-implied deck (rule V19): reverse-solving the model, the US$45.43 price corresponds to a flat long-term WTI of ~US$67/bbl — below the ~US$70 base and roughly US$11 under the ~US$78 spot, i.e. the equity now discounts a conservative deck, the mirror image of the mildly-constructive one it priced at US$52 into the merger close.

7.5 Scenario analysis

Every weighted method is recomputed in three coherent worlds — each WTI deck a rung of the fixed grid (rule V26) — so the blend can be struck per scenario (rule V14).

Table 10. Scenario assumptions and per-method value per share

Source: this analysis; each weighted method recomputed under each scenario’s deck, discount rate and multiple. Illustrative scenarios, not forecasts. The three WTI decks are the US$60 / US$70 / US$90 rungs of the fixed oil grid (Table 3b of the valuation playbook); gas and the discount rate move with each world. The NAV method carries the widest range — the oil-price leverage a shale E&P has by construction.

7.6 Fair value & conclusion

Each weighted method’s value per share is multiplied by its weight and summed to a blended fair value — once per scenario. The blend reproduces on a calculator from the values and weights below.

Table 11. Fair-value blend

Source: this analysis; E&P-producer default weights (rule V18). All figures in US dollars; horizon: spot fair value. Cross-checks carried at 0% weight and discussed in 7.4: PV-10, analyst consensus and the market-implied deck (V19). Base blend = 0.45 × US$49.00 + 0.30 × US$45.49 + 0.25 × US$49.80 = US$48.15. Adding the ~2.8% dividend yield, the implied total return is about +8.8% — reported, not rated.

Figure 9. Value per share by method and scenario

Figure data: Table 11. Shading ranks every cell within this figure’s own US$25.00–US$88.00 range; the base-case blend carries the outline. Current share price US$45.43 (11 Aug 2026). The wide spread down the NAV column is the oil-price leverage; the two relative methods sit tighter around the price.

Conclusion. The blended fair value is US$48.15 in the base case, inside a US$30.47–US$73.23 bear-to-bull range, against a US$45.43 share price — an implied +6.0%. The value read is Fairly valued (wide band): the base sits inside the ±10% band, and the bear case is 33% below the current price — wider than the 25% threshold, so the qualifier travels with the read everywhere it appears. The change from the stale-anchor read is the price, not the business: at US$52 into the merger close the shares carried a small premium to fair value; after a ~13% summer de-rating, against oil that firmed to ~US$78, that premium has become a small discount, with the NAV (~US$49) and the flowing-barrel method (~US$50) both a touch above the price and the EV/EBITDAX method (~US$45.5) right on it. The market-implied read (7.4) says the price discounts only ~US$67/bbl WTI; sell-side consensus of US$59.69 sits well above even a constructive reading of this model. This analysis is deliberately more conservative than the street on the deck and on synergy timing. Assumptions box: valuation date 12 August 2026; market data as of the 11 August 2026 close (US$45.43, ~1,150 m diluted shares, ~US$52.2 bn market cap, ~US$10.9 bn net debt); horizon spot fair value; currency US$; decks WTI bear US$60 / base US$70 / bull US$90 (Table 3b rungs), gas ~US$3.50 base; ~10% discount (8%/12% in the bull/bear); NAV from a simplified corporate FCF model (author-built) on pro-forma combined reserves; weights NAV 45% / EV-EBITDAX 30% / EV-flowing 25%; run-rate EBITDAX ~US$11.5 bn and FCF ~US$5 bn are author estimates; PV-10, consensus and the market-implied deck are unweighted cross-checks. To run the same NAV and multiples across every US upstream name, screen the sector on Metal Pilot.

8. Near-term catalysts (1–3 years)

The combined company’s forward upside over the next two to three years is dominated by turning the merger into per-share value — realized synergies, deleveraging and restored returns — on top of a firmer commodity tape. The most material positives are structural, not speculative.

Table 12. Near-term catalysts (1–3 years)

Source: Devon/Coterra joint proxy statement , Devon FY2025 10-K and Q1 2026 10-Q ; timing reflects company guidance and is not guaranteed.

The common thread is scale, synergies and self-funded returns: the combined company does not need higher prices to integrate, capture savings or fund the dividend — a firmer oil-and-gas tape simply accelerates all three. The swing factor is execution: landing US$1 billion of synergies without losing the cost and capital discipline that both companies were valued for.

9. Rating & verdict

The combined Devon is scored on the Metal Pilot Company Scorecard — the same nine dimensions, on the same ★1–5 scale, that every US upstream name in the series is scored on, so the peers are directly comparable. Each star is relative to the large-cap US independent E&P peer set (Section 2.7) and substantiated below.

Table 13. The combined Devon Energy scorecard

Source: the Metal Pilot Company Scorecard; evidence in Sections 2–7. Peer basis: large-cap US independent E&Ps (Section 2.7). Composite is the archetype-weighted average per the producer/operator weighting (dimensions 1/2/3/5/6 at 15% each, dimensions 4/7/8/9 at 6.25% each).

Weighted average = (0.60 + 0.60 + 0.60 + 0.60 + 0.60) + (0.25 + 0.25 + 0.3125 + 0.25) = 4.06/5 → rounds to the published ★★★★, Solid.

The two-axis verdict. Quality Solid (★★★★) × Value Fairly valued (wide band) → a top-tier operator near a conservative fair value: own it for the scale, the strong balance sheet and enhanced returns, with oil strength and synergy capture the upside. The merger lifts the quality axis a notch above standalone Devon — bigger, more diversified, a longer-life reserve base and still a strong, investment-grade balance sheet (the lone ★★★★★ is jurisdiction) — held back from High quality by a gassier, less oil-levered mix, a still-adequate reserve life and genuine integration risk. The value axis has round-tripped: at US$40.21 pre-announcement Devon was modestly undervalued; the shares re-rated ~30% into the merger close (US$52), then gave much of it back over the summer to ~US$45, so the combined company is again fairly valued — the base-case blend (~US$48) now a shade above the price, with the NAV and flowing-barrel methods carrying modest upside. What tips the verdict is execution and the gas tape as much as oil — whether US$1 billion of synergies lands and Henry Hub firms. This is an analytical read, not a recommendation; operating figures are pro-forma, refined by the combined company’s first results (reported 4 August 2026), on current market data.

For how Devon compares head-to-head with the four other largest US upstream oil producers — EOG, Occidental, Diamondback and Ovintiv — on one shared construction, see US Large-Cap Upstream Oil Producers Compared (2026) .

To go from this single-name view to the whole peer group — screening every US upstream E&P 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

This is an analysis of the combined Devon Energy following its merger of equals with Coterra Energy (closed ~7 May 2026), on a pro-forma basis. The combined financials, reserves, production, share count and standardized measure are from the Devon/Coterra joint proxy statement/prospectus (2026) — its unaudited pro-forma combined statements, prepared as if the merger completed 1 January 2025, together with both companies’ historical columns. Devon’s per-basin operating detail (production, netbacks, costs, hedges, management, ESG) is from Devon’s FY2025 10-K and Q1 2026 10-Q; Coterra’s contribution is at the reserve, production and revenue level from the proxy, because the combined company had not yet issued segment-level reporting as of writing. Market data — share price, market cap, enterprise value, net debt, share count and analyst targets — is as of the 11 August 2026 close (US$45.43, ~1,150 million shares) per stockanalysis.com , after the combined company reported its first quarter on 4 August 2026. Enterprise value, EV/EBITDAX and free-cash-flow yield are derived from those inputs; the NAV is a simplified corporate free-cash-flow model (author-built) on pro-forma combined reserves at the stated WTI/gas deck and a ~10% discount rate, with component PVs illustrative. Combined run-rate EBITDAX (~US$11.5 bn) and free cash flow (~US$5 bn) are estimates built up from the two companies’ figures at the base deck, not disclosed combined results, and the valuation blends three value-per-share methods (NAV 45% / EV-EBITDAX 30% / EV per flowing BOE/d 25%) reproducible from Tables 6–11. WTI (~US$78) and Henry Hub (~US$2.66) spot prices per August 2026 market data. Peer figures are approximate and flagged for refresh. The asset-map figure is omitted deliberately — a five-area onshore US footprint does not render as a legible proportional-symbol map, and this post type draws no SVG (rule A13). Operating figures remain on the pro-forma year-end-2025 reserve basis, refined by the combined company’s first results; market data as of 11 August 2026. Data as of 12 August 2026; refreshed on the combined company’s next quarterly report. Provenance: Devon Energy Corporation / Coterra Energy Inc. — Joint Proxy Statement/Prospectus & 10-K Filing — 2026.

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 12 August 2026, built on the combined company’s first post-close results and pro-forma operating figures, at the 11 August 2026 market price — the share price, multiples and the valuation read all move, and combined operating figures are estimates pending full audited combined reporting. 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 the Devon/Coterra joint proxy and Devon’s filings and reviewed, but readers should verify against the combined company’s own reporting before acting. The author holds no position in Devon Energy as of the date of writing.