Damage Math

Damage Math

Between 31 July 2024 and 8 April 2025 Devon's equity lost $12.7 billion of value. The filed damage to earning power over the same period was a $1.3 billion pre-tax hit from realized prices — and capital guidance fell while production guidance rose. Discounted at 10%, that hit is worth $1.8 billion if temporary and $10.3 billion if permanent. The trial puts the probability it is temporary at 0.71.

The near-term hit, quantified

The framework's canonical setup is a company that cuts its own numbers and a market that capitalizes the cut. Devon did not cut. Across the eight months of the fall it raised production guidance twice and lowered capital guidance three times, and the free-cash-flow figure it published at a constant oil price went up, not down.

Sources: preliminary 2025 outlook and free-cash-flow sensitivities, Q3 2024 earnings deck [1]; improved 2025 outlook, Q4 2024 deck [2]; updated outlooks, Q1 2025 deck [3] and the August 2025 oil guide of 384 – 390 MBo/d on $3.6 – $3.8 billion of capital, Q2 2025 deck [4]; capital and free-cash-flow actuals from the FY2025 Form 10-K sources-and-uses table [5] and production actuals from the same filing's production-volumes table [6]. The November 2024 free-cash-flow figure is read off that deck's sensitivity chart, whose text states a 9% free-cash-flow yield at $70 WTI on the 1 November 2024 market capitalization; the February 2025 figure is the deck's stated floor of more than $3.0 billion. The August 2025 point interpolates between the deck's $65 WTI ($3.0 billion) and $75 WTI ($3.7 billion) bars.

Two of those moves came before the April 2025 crash. At the Q4 2024 call on 19 February 2025, with the stock already 26% below its peak, the CFO said Devon was "bumping our 2025 production and reducing our capital from the soft guide that we provided on the last call" and expected the changes "to drive more than $300 million in additional free cash flow this year" [7]. The third and fourth came after it: the business optimization plan announced in April 2025 targeted "$1.0 billion in annual pre-tax free cash flow improvements by the end of 2026" [8], and by the 6 May call the CEO framed it as delivering "an additional $1 billion in annual free cash flow by year end 2026" [9].

What did fall was the commodity. The trigger the company names in its own filing is external: "commodity prices have experienced heightened volatility and declines, driven primarily by economic uncertainty in global trade arising from geopolitical events and shifting trade policies, such as the imposition of tariffs by the U.S. and planned oil output increases by OPEC+" [10]. WTI averaged $64.87 per barrel in 2025 against $75.79 in 2024, "an approximately 14% decline" [11].

The 10-K puts a figure on that decline. "From 2024 to 2025, realized prices contributed to an approximately $1.3 billion decrease in earnings" [12]. The net-earnings bridge on page 59 itemizes it at −$1,335 million, against +$1,382 million from volumes, −$384 million from production expenses and −$594 million from depreciation, depletion, amortization and impairments; the eight components reconcile exactly to the stated 2024 and 2025 totals of $2,942 million and $2,681 million [13]. The $1,335 million pre-tax realized-price effect is the numerator of everything below.

Free cash flow itself never fell. Operating cash flow less capital expenditures ran $2,661 million in 2023, $2,955 million in 2024 and $3,119 million in 2025, on operating cash flow of $6,544 million, $6,600 million and $6,711 million against capital expenditures of $3,883 million, $3,645 million and $3,592 million [14] [15].

A limitation on the consensus record. The vendor revision feed for this run carries trailing-180-day estimate snapshots taken from 30 January 2026 onward, so the analyst path across the 2024–25 fall cannot be measured directly, and the snapshots that do exist straddle the Coterra merger, which re-based FY2027 consensus revenue from $15.8 billion to $26.6 billion. What the feed can settle is where FY2025 landed against the sell side: normalized EPS came in at $3.92 against a $3.949 mean, and revenue at $17,188 million against a $16,713 million mean — a 0.7% shortfall on earnings and a 2.8% beat on revenue, on the vendor's own definitions, data as of 29 July 2026. Against the eight quarters through Q1 2026 the record is four beats and four misses on normalized EPS, the largest being +15.7% for Q4 2024 and −4.2% for Q1 2026.

The price move over the same window

Sources: closing prices from the daily NYSE feed (peak $47.03, trough $26.80); period-average basic share counts from the Q2 2024 and Q1 2025 Forms 10-Q earnings-per-share notes; net debt is total debt less cash at 30 June 2024 and 31 March 2025 as reported. Market capitalization and enterprise value are derived from those figures.

Holding the share count constant at the 626 million outstanding when the stock peaked, the $20.23 per-share fall destroyed $12.66 billion of value for the holders who owned it at the top. Measured on each date's own share count the figure is $12.21 billion, a 41.5% decline.

Enterprise value fell less — $9.53 billion, or 27.7% — because Devon added $2.7 billion of net debt inside the window. That was not distress: on 27 September 2024 Devon "acquired the Williston Basin business of Grayson Mill for total consideration of approximately $5.0 billion, consisting of $3.5 billion of cash and approximately 37.3 million shares" [16], and the deal brought 247 MMBoe of purchased reserves with it [17]. The enterprise the market was marking down at the trough was materially larger than the one it had marked up at the peak, which makes the equity figure the cleaner measure of what happened to a shareholder and the enterprise figure the more conservative one for what happened to the business.

Set against the near-term hit: FY2025 normalized EPS landed 0.7% below the consensus mean, reported free cash flow rose 5.6%, and the market capitalization fell 41.5%.

The NPV arithmetic

The two-scenario calculation below is deliberately plain. Every input is stated; nothing is modeled that cannot be recomputed from the numbers on this page.

Source: derived. After-tax annual damage of $1,033 million is the $1,335 million realized-price line of the FY2025 net-earnings bridge [18] taxed at the FY2025 effective rate, discounted at 10%; price damage is 626 million shares times the $20.23 peak-to-trough per-share fall.

The workings, line by line:

• Temporary, two years. $1,033m × (1.10⁻¹ + 1.10⁻²) = $1,033m × 1.7355 = $1.79 billion.
• Temporary, three years. $1,033m × 2.4869 = $2.57 billion.
• Permanent, 15-year annuity. $1,033m × 7.6061 = $7.86 billion.
• Permanent, perpetuity. $1,033m ÷ 0.10 = $10.33 billion.
• Split. The permanent slice is the per-unit margin gap that survived at flat benchmark prices: total field-level cash margin was $27.78 per Boe in Q1 2026 against $30.16 a year earlier [19], a $2.38 gap on 75.0 MMBoe of quarterly production, or $714 million a year pre-tax and $552 million after tax. Capitalized in perpetuity that is $5.52 billion; the residual $481 million of the annual hit, treated as temporary over two years, adds $0.83 billion. Total $6.36 billion.
• Probability-weighted. At the trial's ruling of 0.71: (0.71 × $1.79bn) + (0.29 × $10.33bn) = $4.27 billion.

The gap. Against $12.66 billion of price damage, the probability-weighted NPV damage of $4.27 billion leaves $8.39 billion, or 66% of the fall, unexplained by the arithmetic of the problem itself. Against the harshest single reading — the whole hit permanent, capitalized in perpetuity — the gap narrows to $2.33 billion, 18%. On an enterprise-value basis the gap against the probability-weighted case is $5.26 billion; against the permanent-perpetuity case, enterprise value fell $9.53 billion versus $10.33 billion of damage, so on that pairing there is no gap at all. Which framing a reader prefers turns on whether the debt Devon raised to buy Grayson Mill belongs in the numerator, and the answer is that it bought 247 MMBoe of reserves, so it does not.

The company's own filed NPV, as a cross-check

Devon publishes a 10%-discounted net present value of its proved reserves every year. It fell from $19,770 million at year-end 2024 to $18,765 million at year-end 2025 — $1.0 billion, or 5.1% — while future cash inflows fell only 1.5% and the 10% discount deduction barely moved [20].

Sources: standardized measure from the FY2025 Form 10-K supplemental oil and gas disclosures [21]; proved reserves from the same note [22]. Per-Boe figures are derived.

The headline 5.1% understates the like-for-like move, because the reserve base grew 13% over the same year on 443 MMBoe of extensions and discoveries and 43 MMBoe of purchases [23]. Per barrel of proved reserves the standardized measure fell from $9.17 to $7.73, 15.8%. Applying the 2025 per-Boe figure to the 2024 reserve base gives $16.66 billion against $19.77 billion actual — a like-for-like NPV decline of $3.1 billion. Both readings — $1.0 billion headline, $3.1 billion like-for-like — sit inside the range the two-scenario calculation produces, and both sit far below $12.66 billion.

One qualification the filing states plainly: the 16 MMBoe of negative reserve revisions in 2025 were "primarily due to price decreases in the trailing 12-month average for oil and NGLs partially offset by price increases in the trailing 12-month average for gas" [24]. The standardized measure is computed at a trailing price deck; it registers the same price move the equity registered, on the same assets, and it moved a fifth as far.

Temporary or permanent: the trial, and its ruling

The temporary-versus-permanent question was argued by two independent briefs writing from the same corpus, each seeing only its own side, and ruled on by three judges reading in randomized order.

The case for temporary, at its strongest

Cash earning power never fell. Operating cash flow rose in each of the three years through the drawdown — $6,544 million, $6,600 million, $6,711 million — with management stating Devon "generated $6.7 billion of operating cash flow in 2025, demonstrating resilience despite lower oil prices" [25]. The reserve base grew rather than shrank: 1,817 to 2,155 to 2,428 MMBoe, on 443 MMBoe of extensions and 150 MMBoe of positive non-price revisions against 307 MMBoe produced, with proved undeveloped reserves up 33% [26] [27]. The cost base came down and stayed down — the $1.0 billion optimization plan reached roughly 85% through 2025 [28] and by Q1 2026 was "on track to achieve the full $1.0 billion target ahead of our original year-end 2026 timeline" [29]. And the funding breakeven was never approached: Devon's Q2 2025 deck put it under $45 WTI including the dividend [30], against a 2025 WTI average of $64.87 [31].

The case for permanent, at its strongest

Per-unit cash margin eroded in a way the oil price does not explain. Total field-level cash margin fell from $32.76 per Boe in 2023 to $29.63 in 2024 [32] to $24.97 in 2025 [33] — a 23.8% fall against a 16.4% fall in WTI over the same two years, the index having averaged $77.62 in 2023 [34]. Product mix does not explain it: oil was 47.1% of Boe production in 2024 and 46.3% in 2025, gas 27.0% and 27.4% [35]. Every core asset participated: Delaware $34.38 to $25.74, Rockies $32.19 to $23.20, Eagle Ford $41.71 to $35.96. The gap survived into a quarter when benchmark prices rose: Q1 2026 field margin was $27.78 per Boe against $30.16 a year earlier, even though WTI rose 1% and Henry Hub rose 38% [36]. Against FY2022, diluted EPS fell from $9.12 to $4.17 [37] while dividends paid fell from $3,379 million to $619 million [38] [39], debt outstanding rose from $6.4 billion at the end of 2022 [40] to $8.4 billion at the end of 2025 [41], and the forward case now depends on Coterra synergies ramping through 2027 rather than on the standalone asset. Management's own inventory language separates "the front five years versus the back five years", with "much more confidence in that front five years" [42].

The ruling

Source: the profile's adversarial trial record — three blind judges, randomized reading order, ruling as recorded in the run's trial tally. Not a filing figure.

The judges put the probability that Devon's impairment is temporary at 0.71, on a range of 0.68 to 0.78 and a mean of 0.723. The spread is 0.10 and the ruling is not contested. Reading order moved almost nothing: seats that read the temporary brief first averaged 0.71, seats that read the permanent brief first averaged 0.73, a gap of 0.02.

The reasoning converged on the same two facts from opposite directions. The judge who read temporary first called the standardized measure holding at −2.8% over two years on a 34% larger reserve base the decisive evidence for temporary, and the field-margin erosion at flat benchmark prices the decisive evidence for permanent — and weighted the second heavily enough to cap the probability at 0.71. The judge who scored highest, at 0.78, reached it the same way and named the same cap, adding that the permanent brief's EPS exhibit measures from a $95-WTI peak, and that from FY2024 earnings fell 9%, not by half.

The trial also disqualified evidence on both sides. Two temporary exhibits were discounted: the "$1 billion, 100% complete" scorecard is guidance-based and assumes a $1.0 billion term loan is retired after the merger closes, against roughly 85% and $850 million actually achieved through 2025 [43] [44]; and the under-$45 breakeven footnote includes the benefit of a hedge portfolio that rolls off, which the brief omitted [45]. Two permanent exhibits were discounted in turn: the 45 MMBoe of proved undeveloped reserves removed for changed development plans nets against 32 MMBoe of upward revisions to −13 MMBoe, with total proved undeveloped reserves rising 33% [46]; and the "front five years" inventory quote sits inside an affirmatively bullish answer about a ten-year outlook across all five basins, so using it as an indictment inverts the speaker [47].

The ruling is the diagnosis this report carries. Nothing in the analysis above or below overrides it.

Which line broke, and whether it self-corrects

Oil is not the line that broke. Devon realized 97% of the WTI index on unhedged oil in FY2025 and 97% again in Q1 2026 [48] [49]. What broke is the residual barrel — Permian gas and NGLs.

Sources: FY2024 and FY2025 oil realized price, unhedged, from the FY2025 Form 10-K [50] and gas and NGL realizations from the gas and NGL price tables in the same filing [51]; quarterly realizations from the Q1 2026 Form 10-Q [52]. Unhedged realizations as reported; ratios are derived from the same tables.

The Q1 2026 quarter isolates the mechanism. WTI rose 1% and Henry Hub rose 38%, and realized prices still "contributed to a $175 million decrease in earnings … primarily due to lower unhedged realized gas and NGL prices", partially offset by higher oil [53]. Devon's gas fetched $1.66 per Mcf against a $5.05 Henry Hub, and its NGLs $17.80 per barrel against a $72.10 WTI. Annualized, that is the $714 million pre-tax residual carried into the split scenario above — the permanent slice the judges weighted against the temporary case.

Whether it self-corrects is a basis question, and the driver-level consensus underwrites correction rather than assumes it.

Source: driver-level consensus from the run's analyst-model dataset, snapshot dated 29 July 2026. Henry Hub and company realized gas are carried by 14 to 22 contributing brokers; the Delaware Basin line by 4 to 7. Not a filing figure.

Consensus has Devon's realized gas price rising from $1.65 per Mcf in FY2026 to $2.57 in FY2027 against a Henry Hub deck that is flat to slightly lower — a realization ratio moving from 45% to 72%. The Delaware Basin line is starker still: $1.05 in FY2026 to $2.51 in FY2027. That is basis normalization as Permian takeaway is added, expressed as an estimate rather than a fact, and it carries only four to five contributing brokers in the out years.

Three qualifications belong with it. FY2027 and FY2028 are pro forma for Coterra, whose Marcellus gas realizes closer to Henry Hub, so part of the company-level recovery is mix rather than basis repair — and the Delaware line is not insulated either, since the merger deck describes the combination as creating "one of the largest operators in the Delaware Basin" with 746,000 pro forma acres [54]. NGL realizations are not modeled to recover at all — consensus has them at $20.09, $19.70 and $19.72 per barrel across FY2026 to FY2028. And Devon's own Q1 2026 deck claims the Delaware NGL differential "improved ~$2/Bbl from Q1 2025" [55] while the company-wide realization in the 10-Q fell from $22.03 to $17.80 over exactly that period against a roughly flat Mont Belvieu index [56]. A basin-level differential and a company-level realization can both be reported honestly and still point in opposite directions, but the reader is entitled to see that they do.

The cost side of the same driver set moves the other way, and with more contributors: lease operating expense of $9.04 per Boe in FY2025 falling to $8.25, $7.84 and $7.78 across FY2026 to FY2028, and general and administrative expense of $1.57 per Boe falling to $1.04. Devon has named the specific commercial actions behind part of that — $200 million of annual savings from signed Delaware contracts, and a capital baseline cut from $3.9 billion to $3.6 billion [57] — and layered a targeted $1.0 billion of run-rate pre-tax Coterra synergies on top by year-end 2027, split roughly $350 million capital, $350 million operating margin and $280 million corporate on the deck's 2027 exit-rate bar [58]. More than 90% of the 2026 combined capital program is oil-weighted [59], which is to say the stream that broke is the one Devon is spending least to grow.

Where the gap stands now

The gap this tab measures was real and it was large: at $26.80 on 8 April 2025, the price carried $12.66 billion of damage against $4.27 billion of probability-weighted NPV damage, and it did so on a company that had just raised production guidance and cut capital guidance.

It is also closed. At $44.41 the stock sits $2.62 below its July 2024 peak; on the 626 million shares outstanding at that peak, the remaining price damage is $1.64 billion — below even the two-year temporary scenario's $1.79 billion, and far below the $4.27 billion the ruling implies. Devon itself has repurchased roughly 100 million shares at an average $44.02, within a percent of today's price [60], and within weeks of closing Coterra raised the dividend 33% and upsized the repurchase authorization to "$8bn, representing 15% of our market value" [61]. On the framework's own arithmetic, the mispricing that existed at the trough does not exist at this price. The drawdown anatomy is in Dislocation; what the current price implies about adjusted cash yield is in Yield; the buyback mechanics are in Self-Help.

Two things would change this read. If FY2026 and FY2027 field-level cash margin fails to recover toward the 2024 level of $29.63 per Boe with WTI near $70 — that is, if the Q1 2026 gap of $2.38 per Boe persists — the permanent slice is larger than $714 million a year and the split scenario understates the damage. If year-end 2026 proved reserves fall on non-price revisions, or the standardized measure drops materially at a flat SEC price deck, the price mechanics reading converts into genuine asset impairment and the whole calculation moves toward the permanent pole.