Chord Energy Corporation (NASDAQ: CHRD) — The Dividend Was the Return, and the Dividend Is 73% Smaller

Independent equity research · Initiating coverage · Report date 1 August 2026 · Price $140.38 (close, 31 July 2026) · Market cap $7.90bn · Enterprise value $9.16bn · Sector: Energy · Oil & Gas Exploration & Production (Williston Basin)

Sections 1–15 below contain no recommendation and no price target; valuation is discussed only as embedded expectations and scenarios. The single deliberate exception is the Claude's Take block immediately below.

⚡ Claude’s Take

This block is the author’s own subjective opinion, set deliberately apart from the position-free analysis that follows. It is general information and commentary, not investment advice, and it is not a recommendation to buy or sell any security. The analysis in Sections 1–15 below carries no position, no recommendation and no price target. Do your own work.

AVOID at $140. Not a short. Revisit at $85–105.

Tag: you are buying an oil-price option with a 1.6%-ROIC business attached — and the option is priced off Tehran.

Chord is a genuinely well-run operator with the best balance sheet in its peer group, sitting on the largest acreage position in the Williston Basin, and it is not expensive at 4.1x EV/adjusted EBITDA. I still would not own it here. The reason is not the multiple; it is that the multiple is correctly where it is. Over five years Chord grew production 4.8x through two transformational mergers and five bolt-on deals, and lifting cost per barrel went from $9.63 to $9.73. ROIC fell from 49.7% to 1.6%. Free cash flow per share fell 72%. The drill bit replaced 58% of three-year production at a ~1.0x recycle ratio, meaning the cash margin on a barrel roughly equals the cost of finding its replacement — leaving nothing for G&A, interest, tax or the equity. Every reserve-base increase since 2023 was purchased. Against that, Diamondback trades at ~6–7x because its barrels lift for $5.55 and recycle at ~3.5x. Chord’s discount to Diamondback is not a mispricing; it is a scorecard.

The entry zone matters more than the verdict. At $85–105 — ~2.7–3.2x EV/adjusted EBITDA and ~0.67–0.79x PV-10 at the $65.34 SEC deck — you are paid for the cost structure and the balance sheet does the rest: 0.58x net leverage, zero drawn on a $2.75bn borrowing base, and no maturity before October 2030 mean this equity survives $50 WTI without a financing event. That is precisely where the stock traded from April 2025 to January 2026, so the zone is not hypothetical. At $140.38 you are instead capitalising a ~$70 WTI world at 8–12x free cash flow, with only 36% of remaining-2026 oil and ~13% of 2027 hedged, in a business whose reserve life is shortening (9.1 years, from 10.4) while it buys reserves. The framing is value, not momentum and not a falling knife — the factor model zeroes Chord’s Momentum loading in three of four specifications while Value and DividendYield carry it, the price sits above all three EMAs and 66.6% above the 52-week low, and the three-year Sharpe is 0.03 against a −53.9% drawdown. This is a mean-reverting, high-volatility commodity-beta name in the middle innings of a recovery driven by the oil factor, not by the company: the multiple expanded 37% since year-end on a flat EBITDA base. The 2026 return is a rented geopolitical premium — the June ceasefire took 25% out of the stock in six weeks and the 20 July repudiation put 24% back in three.

The catchy line is the honest one. Over the last three years the share price is −10.8% and the total return is +4.8%: every dollar of three-year return was the dividend, and the dividend has been cut from $4.80 a quarter to a $1.30 flat base — 73% smaller — with management confirming in May 2026 that variable dividends are not coming back and excess cash goes to the balance sheet instead. Anyone extrapolating the five-year total-return record is extrapolating a capital-return policy that no longer exists.

Conviction: medium. Flips bullish if LOE/Boe breaks below $9.00 for two consecutive quarters and Chord raises its fourth-mile toe-contribution assumption from 80% toward 100% on produced data — that combination would convert the 4-mile program from a claim into a corporate cost-down and would legitimise the inventory count. Flips bearish if WTI sits below $65 for two quarters with 2027 hedges under 15%, pushing free cash flow toward $700M against a $1.4bn maintenance budget and a $293M annual base dividend.

📈 Stock Price Action — Five-Year Event Map

Chord’s five-year chart is a round trip with a dividend attached. The stock first traded at ~$31 on 20 November 2020, the day Oasis Petroleum emerged from Chapter 11; it peaked at an all-time closing high of $187.42 on 11 April 2024 (intraday $190.23 the following session); and it closed at $140.38 on 31 July 2026 — ~25% below the closing high, but only ~17% below its all-time total-return high, the ~8-point wedge being the dividend stream. The 52-week range is $84.25–$151.95: today’s price sits 7.6% below the 52-week high and 66.6% above the 52-week low, above its 21-, 50- and 200-day EMAs (+8.2%, +8.9%, +17.8%). The number that matters most is not on the chart: over three years the share price is −10.8% while the total return is +4.8%. Every dollar of three-year return came from dividends — and that dividend has been cut ~73% from its peak.

Cycle narrative. (1) The entity that trades today began on 19 November 2020 with fresh-start accounting that erased ~$8.65bn of gross oil and gas property; the first leg up is a recapitalised balance sheet re-rating off a $20 intraday low, not operating progress. (2) The 2022 leg is the Ukraine crude spike, with the Whiting merger-of-equals announced on 7 March 2022 (shares +5.2% that session). (3) The June–July 2022 fall looks like a crash and largely was — a Fed-driven recession scare hit crude hard — but roughly 8 percentage points of it is the mechanical ex-dividend of the $15.00/share Whiting-close special on 1 July; this is the widest gap in the record between price and total return. (4) The 2022–24 climb is the variable-dividend era: $75–90 WTI funding $3–5 quarterly payouts, with the Enerplus all-stock merger announced 21 February 2024 and closed 31 May 2024 — the all-time total-return high is the Enerplus closing date, which in hindsight marks the top. (5) The −56% drawdown that followed is the single most important stretch: OPEC+'s 2 June 2024 decision to unwind voluntary cuts began it and the April 2025 tariff shock finished it, with four of the six largest single-day moves in the five-year record falling in one week of April 2025. The variable dividend was cut alongside it, $2.94 → $2.52 → $1.44 → a $1.30 base. (6) 2025 was a second round trip to a $84.25 low, during which Chord announced the $550M XTO Williston acquisition (15 September) and funded it with an upsized $750M 6.000% senior note due 2030 (priced 16 September) — and a Q3 earnings beat was still sold, because the tape was trading crude, not the company. (7) The entire 2026 advance is geopolitical: strikes on Iran from 28 February drove WTI above $100 for the first time since July 2022, and Chord ran from ~$104 to ~$146 in five weeks; notably, the large Q1-26 beat and guidance raise on 5 May was followed by a 5.6% decline the next session. (8) The June ceasefire removed the premium and took 25% out of the stock in six weeks; Iran’s 20 July repudiation of the MoU put it back and the stock retraced on below-average volume. The five-year record is a commodity chart with a corporate story layered on top — and the corporate story has been dilution.

1. Executive Summary

Chord Energy is the largest acreage holder and the top producer in the Williston Basin, with 1,302,921 net leasehold acres, ~277 MBoe/d of production, 917.5 MMBoe of proved reserves and a balance sheet that is the best in its peer group. It is also a company whose per-unit economics have deteriorated monotonically as it has scaled, and whose scale was purchased rather than created.

The central finding of this report is an arithmetic one. Between FY2021 and FY2025 Chord increased production 4.8x — from 58.0 to 276.6 MBoe/d — through the Whiting merger-of-equals (July 2022), the $4.61bn Enerplus acquisition (May 2024) and five Williston bolt-ons including the $542.2M XTO package (October 2025). Across that expansion, lease operating expense per Boe went from $9.63 to $9.73, and is $9.87 in the most recent quarter. General and administrative expense fell hard and genuinely — $3.39 to $1.00 per Boe — and gathering and transportation fell from $5.79 to $2.88, but together those wins saved $5.30/Boe against a $29.47/Boe collapse in realized revenue. Eighty-nine percent of the margin destruction was price; the cost line offset eleven percent of it. Return on invested capital fell from 49.7% to 1.6% (6.1% adding back the goodwill impairment). Free cash flow per share fell 72%, from $43.18 to $11.97, while weighted diluted shares rose 180%.

The reserve base tells the same story from the other end. Over 2023–2025 Chord replaced 58% of the barrels it produced with the drill bit, at a three-year organic finding-and-development cost of ~$25.55/Boe against an average field cash margin of ~$26.50/Boe — a recycle ratio of approximately 1.0x. The reserve base nevertheless grew from 636 to 918 MMBoe, because Chord bought 372 MMBoe for $6.23bn. Revisions to previous estimates were negative in each of the last three years (−100.6 MMBoe cumulatively), and total reserve life shortened from 10.4 to 9.1 years — in a year in which the company purchased 38 MMBoe. Diamondback, for contrast, runs a ~3.5x recycle ratio on $8.52/Boe of proved-developed F&D.

What is genuinely good deserves equal precision. Net debt/EBITDA is 0.58x, the revolver is undrawn against a $2.75bn borrowing base reaffirmed twice, liquidity is ~$2.16bn and there is no maturity before October 2030. The crude differential is tight at −$2.02/Bbl (−3.2% to WTI). Cash G&A of $1.00/Boe is competitive and represents real synergy capture. Well-level capital efficiency is improving — a 37% reduction in drilling-and-completion cost per foot over four years — and the 3- and 4-mile lateral program is a real, basin-specific operational advantage that the Permian’s fragmented ownership largely cannot replicate. None of it, however, constitutes a moat: there is no cost advantage visible in lifting cost, no customer captivity in a NYMEX-referenced commodity, and no economies of scale that survive contact with the per-unit data.

Capital allocation is disciplined on leverage and procyclical everywhere else. Chord repurchased $442.8M of stock at an average $142.20 in FY2024, then — holding a freshly enlarged $1.0bn authorisation with the shares at a 52-week low of $84.25 — spent $10.0M in the whole of Q4-2025 at $97.01, leaving $952.2M unused. The 2025 executive cash-incentive scorecard paid 120% of target in the year Chord wrote off 100% of the Enerplus goodwill ($539.3M), earned a 2.0% return on equity and delivered an absolute TSR worse than −10%. The scorecard contains no return-on-capital metric; its single profitability measure is a company-defined, EUR-denominated F&D that paid at 142%.

At $140.38 the equity capitalises roughly a $70 WTI world at 8–12x free cash flow, using management’s own two-point sensitivity (~$700M of 2026 FCF at $64 oil; ~$1.4bn at $80). Enterprise value is 1.01x PV-10 at the $65.34 SEC deck, meaning the market ascribes essentially nothing to unbooked inventory at that deck. The multiple has expanded 37% since year-end 2025 on an unchanged EBITDA base — the 2026 move is multiple, not earnings, and the multiple moved with an OilPrice factor now 2.4 standard deviations extended. Chord carries a +1.99 loading on it.

2. Business Overview

What the company is. Chord Energy Corporation is an independent exploration and production company operating almost entirely in the Williston Basin of North Dakota and Montana, targeting the Middle Bakken and Three Forks formations, with a small non-operated interest in the Marcellus Shale inherited from Enerplus. It is a Delaware corporation headquartered in Houston, filing under CIK 0001486159 — the legacy Oasis Petroleum registrant. The corporate history matters to every number in this report: Oasis emerged from Chapter 11 on 19 November 2020 with fresh-start accounting; merged with Whiting Petroleum on 1 July 2022 to form Chord; acquired Enerplus Corporation on 31 May 2024; and closed a $542.2M Williston package from ExxonMobil’s XTO Energy on 31 October 2025. Management describes the XTO deal as “Chord’s fifth Williston Basin deal in 5 years.”

Scale and asset base (all as of 31 December 2025, per the FY2025 Form 10-K). 1,302,921 net leasehold acres in the Williston — “the largest acreage position of any operator in the Williston Basin” — of which approximately all is held by production; 1,334,679 total net acres including the Marcellus. 5,025 gross (3,937.3 net) operated producing wells at an average 78% working interest, within 10,528 gross (4,415.0 net) total productive wells. 89% of proved reserves are attributable to operated properties. Proved reserves of 917.5 MMBoe, 69% proved developed, 56% crude oil. Four operated rigs running at year-end, with four to five planned for the majority of 2026. In 2025 Chord completed 307 gross development wells — 242 gross oil wells, all Williston, and 65 gross non-operated Marcellus gas wells — and no exploratory wells in 2023, 2024 or 2025. Approximately 6% of the Williston net acreage is federal mineral acreage.

How it makes money, and the one line that distorts everything. Chord sells crude oil, NGLs and natural gas “to refiners, marketers and other purchasers that have access to nearby pipeline and rail facilities,” managing its marketing in-house. Revenue therefore splits into two utterly different components:

Purchased oil and gas sales are third-party barrels Chord buys and resells for marketing and logistics reasons. The offsetting expense sits one line below, and the margin is between 0.18% and 0.50% — it was negative in FY2021 and FY2022. In FY2024 this activity was 27.0% of “total revenues” and contributed $2.6M of gross profit. In Q1-2026 the line quadrupled from $111.6M to $515.0M with no accompanying disclosure, and it accounts for the entire headline revenue “growth” of the quarter: total revenues rose 37.1% year over year while oil, NGL and gas revenues rose 4.3%. Any revenue-based statistic on Chord — EV/Sales, revenue growth, gross margin on total revenue — is meaningless unless the gross-up is stripped out first. This report uses oil, NGL and gas revenue throughout.

The barrel itself. Chord’s production is 56–57% crude oil on a Boe basis, and the economics of the three streams could hardly be more different:

The crude differential is genuinely tight — 3.2% off WTI is competitive and reflects the basin’s established takeaway. But the other 44% of the Boe stream earns almost nothing: FY2025 NGLs at $7.22/Bbl are ~11% of the crude price, and Williston gas at $1.40/Mcf is barely above the cost of moving it. CFO Robuck quantified this on the Q2-2025 call: NGL realizations run at “9% of WTI” and gas at “32% of Henry Hub,” and “certain marketing fixed fees are deducted from our NGL and natural gas prices,” which levers those realizations in both directions. This is why Chord’s blended $38.60/Boe realization in FY2025 sits below Diamondback’s ~$40 despite Chord’s higher oil weighting — the associated stream drags the average down.

Recurring versus non-recurring. Effectively all revenue is non-contracted commodity sales at spot-referenced prices. There is no subscription, no take-or-pay, no backlog. The only structural recurrence is decline: a producing well base of ~5,000 operated wells that declines annually and must be replaced with capital. Management’s 2026 budget of $1.35–1.45bn is, by its own description, a flat-production budget — “a low to no oil growth program, yielding average volumes of 157,000 to 161,000 barrels of oil per day” (CEO Brown, Q4-2025 call). Maintenance capital is therefore ~$1.4bn, which is ~69% of FY2025 operating cash flow, and growth capital is approximately zero.

The Marcellus stub. A non-operated gas interest that realized $6.40/Mcf in Q1-2026 against a $3.14 blended gas price — disproportionately valuable per unit, immaterial in size. Management has called it “non-core” on four consecutive calls while holding it: “We are absolutely open to divesting it, but we want to do so in a manner that maximizes value” (Brown, Q1-2026). There is no disclosed carrying value, no process and no timetable. It is an unpriced sum-of-the-parts stub.

Verdict. A pure-play, price-taking commodity producer with genuine operating scale in a single mature basin, a favourable crude differential, a near-worthless associated stream, and a revenue line that must be manually cleaned before it can be analysed at all.

3. Industry Dynamics

Structure. US onshore exploration and production is the textbook price-taking industry: a large number of independent producers selling an undifferentiated product into a global market whose price is set by OPEC+ policy, macro demand and geopolitics. No producer in the Lower 48 has pricing power. Profit pools are therefore determined almost entirely by two variables the producer partly controls — cost per barrel and capital intensity per barrel of reserves added — and one it does not control at all. That framing is not a rhetorical device; it is the arithmetic of Chord’s own five-year record, in which 89% of the change in field cash margin was price.

The Williston specifically: a mature basin with one unique structural advantage and one structural handicap.

The handicap is cost. The Bakken is a deeper, colder, more infrastructure-intensive play than the Permian, with higher fixed costs per well and a produced-water burden that scales with a long-lived, high-water-cut well population. This is not our characterisation alone: on the Q4-2025 call, William Blair’s Neal Dingmann framed the issue directly as “Bakken generally having a bit more fixed cost than other areas of the Permian,” and CEO Brown did not dispute it — he answered only with continuous-improvement effort. The peer data supports the framing unambiguously. FY2025 lease operating expense per Boe: EOG $3.72, Ovintiv $3.80, Permian Resources $5.26, Diamondback $5.55, APA $8.86 (burdened by the North Sea), Chord $9.73. Chord’s lifting cost is 1.75x Diamondback’s and 2.6x EOG’s.

The advantage is lateral length, and it is real. North Dakota’s spacing and unitisation regime, combined with large contiguous blocks held by production, uniquely permits 3-mile and now 4-mile laterals — a geometry the Permian’s fragmented surface and mineral ownership largely forecloses. Chord’s own claim (COO Henke, Q2-2025) is that “relative to a 2-mile well, 4-mile wells are expected to recover 90% to 100% more EUR for only 40% to 60% more CapEx,” translating to “an $8 to $12 per barrel cost of supply reduction yielding up to 30% lower F&D costs.” Brown’s corporate arithmetic: if half the inventory converts to 4-mile development, “maybe that’s a $5 improvement” per barrel company-wide. This is a hypothesis, not evidence — as of Q1-2026 Chord had 12 four-mile laterals producing and 33 drilled — but it is the single most credible source of forward per-unit improvement in the file, and it is basin-specific rather than company-specific, which matters for the moat question in Section 4.

A related structural point in the basin’s favour: Brown claims “the Bakken delivery from a well has the lowest standard deviation of delivery from any Lower 48 basin out there.” Plausible for a well-characterised, single-target play with two decades of horizontal history, and consistent with Chord’s conservative spacing. But low dispersion is a risk-management virtue, not a returns virtue. It narrows the distribution of outcomes around a mean return that the oil price sets.

Maturity. The clearest evidence that the Williston is late-life is Chord’s own reserve arithmetic. Total reserve life fell from 10.4 years to 9.1 years, and proved-developed life from 7.3 to 6.2 years, over 2024–2025 — in a year in which the company purchased 38 MMBoe of reserves. A basin in its growth phase does not produce that pattern in its largest operator. Consolidation is the recognised end-state response, and Chord is executing it: five deals in five years, and management is explicit that it is “inquisitive and acquisitive by nature.” Notably, the counterparty on the most recent transaction was ExxonMobil, which sold.

Regulation. North Dakota is a comparatively constructive jurisdiction — the state cut production tax rates over the period, which is visible in Chord’s production taxes falling from $5.25/Boe (FY2022) to $2.89 (FY2025). Federal exposure is modest at ~6% of net acreage, limiting permitting risk relative to Permian and Rockies peers with heavy federal footprints. Gas capture requirements are a genuine operating constraint in the basin and appear in Chord’s own incentive scorecard as an environmental metric. None of this is thesis-determinative.

The capital cycle (Marathon lens, per the frameworks skill). The most interesting industry datapoint is a two-sigma divergence. Over the trailing 252 days the OilPrice factor returned +22.0% over 126 days (z +2.43, extreme) while the Oil & Gas E&P industry factor returned −26.4% (z −2.16, extreme) and −29.5% over 756 days; the broader Energy sector factor is −17.2% over 756 days. The commodity is being rewarded and the equities that produce it are being punished, simultaneously, at the extremes of both distributions. In Marathon’s framework, capital exiting an industry while the underlying commodity rallies is the supply-side signature that precedes above-normal returns — under-investment creates scarcity value.

That is a constructive read for the sector. It is not obviously a constructive read for Chord, and the distinction is the point. The capital-cycle framework rewards the disciplined non-investor and punishes the marginal buyer of assets. Within the Williston, Chord is the marginal buyer: five acquisitions in five years, $6.23bn spent on 372 MMBoe of purchased reserves over 2023–2025, a ~1.0x recycle ratio on the drill bit, negative reserve revisions in each of the last three years, and asset growth that has been accompanied by a collapse in return on capital from 49.7% to 1.6%. Marathon’s asset-growth anomaly is a warning about exactly this profile. The capital cycle may well reward Williston barrels; it has not so far rewarded the entity assembling them.

Verdict: a structurally average-to-poor industry position. Price-taking economics with no pricing power, in a mature basin with a favourable crude differential, a near-worthless associated stream, materially above-average lifting costs, and one genuine, late-arriving geometric innovation in lateral length. The sector-level capital cycle is constructive; Chord’s position within it is not.

4. Competitive Position

The question is not whether Chord is well run. It is. The question is whether anything about its position would cause a financial outcome to deteriorate if a competitor tried to replicate it — the only definition of a moat that survives contact with a P&L. Applying the Greenwald taxonomy directly:

Supply-side / cost advantage — FAILS, and this is the load-bearing finding of the report.

Five years. Two transformational mergers. A 4.8x increase in volume. An explicit continuous-improvement programme and three separate rounds of synergy claims. Lifting cost per barrel is higher today than it was in 2021. A company with an economies-of-scale cost advantage does not produce that table. The genuine wins — gathering and transportation halved, cash G&A cut by two-thirds — are real and management deserves credit for the G&A synergy capture; together they saved $5.30/Boe against a $29.47/Boe collapse in realized revenue.

The consequence shows up as the thinnest cash margin in the coverage set:

There is a second-order consequence that matters for how the equity behaves. At a 59.8% cash margin, a $10/Bbl move in WTI (~$9.70 realized on a 3% differential) swings Chord’s field cash flow by ~$549M — 24.6% of FY2025 adjusted EBITDA. A peer at a 75% margin absorbs the same absolute move against a larger denominator. High-cost barrels are high-beta barrels, and Chord’s operating leverage is the highest in the group.

Demand-side / customer captivity — NOT APPLICABLE, definitionally. Chord sells an undifferentiated commodity into NYMEX-referenced markets to “refiners, marketers and other purchasers.” There are no switching costs, no habit, no search costs, no brand. The one realization advantage — a −3.2% crude differential — is a function of basin takeaway infrastructure available to every Williston operator, not of Chord’s franchise. If a customer switched suppliers tomorrow, nothing in Chord’s P&L would change.

Economies of scale plus captivity — FAILS on both legs. Scale unambiguously exists: the largest acreage position in the basin, top producer status, 89% operated reserves, and real operational consequences management can name — longer laterals across contiguous blocks, multi-well pads into multiple formations, centralised production and fluid-handling facilities, reduced rig mobilisation, in-house marketing. But scale without captivity is not a barrier to entry; it is merely size. And the Greenwald financial tests both fail:

• Market-share stability: Chord’s Williston share is not stable-by-construction. It was bought, five times in five years. A share position assembled by acquisition at market-clearing prices is the opposite of the incumbency advantage the test is designed to detect.
• Return on invested capital: ROIC fell 49.7% → 27.2% → 19.0% → 8.9% → 1.6% (6.1% adding back the goodwill charge) as capital was added. On the honest denominator — NOPAT over gross oil and gas property, which gives no credit for depletion already run through the P&L — FY2025 is 1.0%, or 3.8% ex-goodwill. Chord cleared its ~12–13% cost of capital in FY2021–FY2023 and failed it in FY2024 and FY2025. The three years it cleared the hurdle coincided exactly with the post-COVID oil spike.

The hardest available test, and Chord fails it. If Chord’s operational differentiation were economically meaningful, it should be detectable in how the equity behaves relative to the generic basket. It is not. FactorsToday’s cosine similarity of CHRD to the XOP E&P ETF is 0.9836, and to the 2x-levered GUSH 0.9838. Statistically, the market cannot distinguish Chord from the E&P index — it is an XOP proxy with ~20% annualised idiosyncratic volatility layered on. Its closest factor twins are Murphy Oil (0.990), Matador (0.988), Devon (0.987) and APA (0.987). Whatever the 4-mile program, the consolidation record and the sub-0.6x leverage are worth, they have produced no distinct factor footprint over a 756-day window.

One further cross-check is worth stating because it cuts for Chord and against a lazy reading. For a ~56%-oil Williston pure-play, Chord’s equity oil beta of 1.996 is only mid-pack — below SM (2.705), Crescent (2.492), APA (2.472), Northern (2.381), Murphy (2.340), Matador (2.308), Ovintiv (2.103) and Permian Resources (2.066). The explanation is not hedging: only 36% of remaining-2026 oil and ~13% of 2027 is protected, and the collar ceilings ($77.65–$81.92) and swaps ($69.54) currently cap Chord into a rallying tape rather than protecting it. The explanation is the balance sheet — 0.58x net leverage and 15.5% net debt to equity against peers running multiples of that. A pure-play oil producer with a mid-pack oil beta is making a balance-sheet statement, not a hydrocarbon-mix statement. The corollary is uncomfortable: a ~2.0 equity beta on a 0.58x-levered balance sheet implies an unusually high asset beta. The barrels are high-beta because they are high-cost, and the clean balance sheet is masking it. If Chord ever levers up for another acquisition, equity beta should rise faster than the leverage arithmetic alone implies.

Verdict: no durable competitive advantage. Chord is a competent, disciplined operator of structurally high-cost, low-associated-value barrels in a mature basin. Its advantages are operational and replicable (better execution, longer laterals available to any operator with contiguous North Dakota acreage) and financial (a conservative balance sheet, which is a choice, not a moat). If a moat claim cannot be tied to a financial outcome that would deteriorate without it, it is not a moat. Nothing here passes that test.

5. Growth History and Forward Opportunities

The history: all of it was bought. Production grew 4.8x, from 58.0 MBoe/d in FY2021 to 276.6 MBoe/d in FY2025. The sources are exhaustively identifiable: the Whiting merger-of-equals (closed 1 July 2022), the Enerplus acquisition (closed 31 May 2024), and five Williston bolt-ons in five years culminating in the $542.2M XTO package (closed 31 October 2025). Over 2023–2025, organic reserve replacement was 58% of production and there were no exploratory wells completed in 2023, 2024 or 2025. The reserve base rose from 636 to 918 MMBoe entirely because Chord purchased 372 MMBoe for $6.23bn.

The per-share consequence is the number that matters. Weighted diluted shares rose from 20.6M to 57.9M — +180% — while operating cash flow was essentially flat across four years ($1,924M in FY2022 to $2,041M in FY2025, +6%). Free cash flow per share fell from $43.18 to $11.97, a 72% decline. Chord has since retired 9.0% of the share count (61,879,575 shares outstanding at 1 August 2024 to 56,299,183 at 4 May 2026), which recovers a fraction of what was issued, at prices well above where the shares traded when the goodwill from the issuing transaction was impaired.

Three specific tests of whether the acquired growth was worth acquiring:

1. Enerplus. $4,611.3M of total consideration, including 20,680,000 shares booked at $3,732.1M. In its stub period from 31 May to 31 December 2024 it contributed $81.7M of pre-tax income — roughly $140M annualised on $4.6bn of consideration, a ~3.0% pre-tax return. The associated goodwill of $539.8M was 100% impaired within 13 months.
2. XTO. $542.2M for ~9,000 Boe/d including ~6,000 Bo/d, implying ~$60,000 per flowing Boe/d. Q1-2026 production of 24,805 MBoe was below Q4-2025’s 25,101 MBoe, despite the package having closed on 31 October 2025. The acquisition bought no sequential growth.
3. The combination against its own deck. The Enerplus announcement showed pro forma combined 4Q23 production of 287 MBoepd. FY2025 actual was 276.6 MBoe/d and Q1-2026 was 275.6 — roughly 4% below the pro forma combination two years later, despite ~$1.09bn of subsequent cash acquisitions. Management characterises this as deliberate maintenance-mode discipline, and that characterisation is honest and consistent with its stated strategy. The arithmetic is nonetheless that the combined entity produces less than the deal deck showed.

Forward: by design, there is no volume growth. Brown, Q4-2025: “we intend to run a low to no oil growth program, yielding average volumes of 157,000 to 161,000 barrels of oil per day, with capital of $1,400,000,000.” When asked on the Q1-2026 call whether ~$100 oil justified more activity, he declined: “I think at this point, we are pretty happy with our activity levels… I do not think there is a lot of efficiency improvement we would pick up by pushing incremental activity through the system.” Asked what would trigger growth, he named durability rather than price: “It is not necessarily a specific price, but whether the durability in the macro setup supports that price over the long term… we have seen significant behind-choke volumes in the global market that could come to market at any time,” and even then only “probably mid-single digits.”

This is genuinely creditable capital discipline — the correct response to a 2.4-sigma commodity move is not to chase it with a rig programme — and it deserves to be recorded as such. It also means the forward equity case cannot rest on volumes. It rests entirely on cost per barrel.

The forward opportunity set, ranked honestly.

1. The 4-mile lateral program — the only identified source of genuine per-share value creation. 2026 plan: ~40% of turn-in-lines and ~60% of spuds are 4-mile, with ~80% of TILs being “longer laterals” (3- or 4-mile). The first full four-mile drilling-spacing-unit development — the Tuni pad, five wells including one alternate shape — was turned in line in Q1-2026 with clean-out to total depth on all wells and “execution and early performance… in line with expectations.” Twelve 4-mile laterals are producing and 33 drilled. The first, the Rystedt, “outperformed its type curve by 30%.”
2. The telegraphed inventory upgrade. Chord currently underwrites only 80% contribution from the fourth mile. Brown, Q1-2026: “Just like the three-mile laterals — after we got enough production history, we said we were no longer underwriting that last mile at 80%; we moved that up to 100% because we were seeing it in the production data. I think it would be a similar case for four-mile laterals.” This is the single largest identified upside optionality in the story. It is also the single largest place where the inventory count depends on a management assumption rather than produced data.
3. Base-production optimisation across ~5,000 operated wells — workovers, cycle-time reduction, chemical treatment, artificial-lift optimisation using machine learning, with the production-engineering team bifurcated between ESP and rod-pump populations. Management reports “a dramatic increase in productivity on our older wells” and “arresting decline.” Real, but modest and hard to size; when asked to quantify the AI savings, management said “To quantify that at this point, I think it’s pretty tough.”
4. Midstream contract repricing worth “$30 million to $50 million a year” as 15-year contracts written in 2010–2014 roll off into a more competitive market. Real, and already partly in the numbers — but inherently finite and non-recurring. Do not capitalise it.
5. XTO re-permitting and re-spacing — “more of a late 2027 phenomenon… more likely going into 2028.”
6. Unquantified optionality explicitly outside the inventory count: deeper benches and the stacked Three Forks column (“we are aware of the full column that sits underneath our acreage position there. We are watching what others do”); infill and refrac potential (“We really have not quantified that yet… it would be a small piece”); alternate-shape/hairpin wells addressing ~10% of long-term inventory at “just a few percentage points more expensive” than a straight lateral.

The inventory question, which is where the growth case actually lives. Management claims ~10 years of inventory and has claimed ~10 years for five consecutive years, including at the February 2024 Enerplus announcement. Two important qualifications, one favourable and one not. Favourably, the count is screened at a sub-$60 WTI breakeven — “The inventory that we put out there is really low sub-$60 WTI inventory, and that determines the count” — which is a genuinely conservative disclosure convention relative to peers, and any cross-peer inventory comparison must normalise for it. Unfavourably, management’s own description of where the additions come from is a reclassification mechanism, not new rock: “some things that we always thought were inventory are just now better inventory than we had before, and then some things before that would not have made sense for us to drill now have really compelling returns as we look at the cost structure.” That works in both directions. A higher cost structure or a lower strip re-disqualifies the same locations. This is the key falsification test for the inventory-depth claim, and it is the reason the LOE trend matters so much more than it appears to.

Verdict: low-quality growth historically, and no volume growth ahead by design. The historical growth was purchased with equity at a 180% increase in the share count and produced a 72% decline in free cash flow per share. The forward case is entirely a per-barrel cost case resting on a 4-mile program with 12 producing wells of evidence behind it.

6. Financial Quality

Income statement, five years.

Four quality-of-earnings flags govern how any of this can be read.

QoE flag 1 — the purchased-volume gross-up, addressed in Section 2. Total revenue is inflated by up to 27% by a zero-margin activity, and the distortion is growing: the line quadrupled in Q1-2026 with no disclosure.

QoE flag 2 — derivative marks dominate GAAP earnings, and realized settlements are trivial. FY2025’s $127.6M derivative gain comprised $63.8M realized and $61.6M unrealized. In Q1-2026 Chord booked a $241.5M net loss on derivatives as oil rallied, against $94.3M of pre-tax income. Management’s adjusted EPS of $4.56 compares to GAAP diluted EPS of $1.90 — a $2.66 per share, 58% gap. Anchor on operating cash flow and realized settlements; never on GAAP net income and never on adjusted EPS.

QoE flag 3 — hedge settlements sit in investing, not operating, cash flow. Chord classifies commodity derivative settlements in investing activities (FY2023 −$268.9M, FY2024 −$12.7M, FY2025 +$56.3M), where most peers run them through operations. FY2023 reported operating cash flow of $1,819.9M therefore overstates comparable cash generation by $268.9M, or 17%, relative to a peer using the conventional presentation. It is disclosed and permissible. It also flatters the headline, and any OCF-based peer comparison or multiple must be adjusted.

QoE flag 4 — a prior-period tax error corrected through the current quarter. The Q1-2026 effective tax rate was negative 15.2%, versus +25.0% a year earlier. Per Note 12: the rate was below statutory “primarily as a result of the identification of an error in the tax provision for the three and six months ended June 30, 2025 pertaining to the impact of goodwill impairment on the Company’s deferred taxes on unremitted earnings. As a result, the Company recognized an additional income tax benefit of $41.8 million during the three months ended March 31, 2026.” Chord deemed the misstatement immaterial and did not restate. GAAP Q1-2026 net income of $108.6M therefore contains a $41.8M out-of-period correction of a FY2025 error — 38% of the reported quarter. Normalised, Q1-2026 net income is ~$66.8M, or ~$1.18 per diluted share. Cash taxes paid in the quarter were $21.0M.

Impairments and the full-cycle test. The defining item of FY2025 is the goodwill write-off. Goodwill went from $0 (31 December 2023) to $539.8M on the Enerplus close, to $0 at 30 June 2025 — a $539.3M charge, taken because of “the decrease in the price of our common stock during the three months ended June 30, 2025.” Because the goodwill was non-deductible, the FY2025 effective tax rate was 81.7%, against 23.7% in FY2024.

The accounting reading is that in an E&P purchase-price allocation, goodwill is usually the deferred-tax gross-up plug: fair value is assigned to reserves, a deferred tax liability is booked on the book-versus-tax basis difference, and goodwill absorbs the residual. It was never an economic asset, so the write-off is less “new information about Enerplus” than an admission that the deal was struck at a price the reserves could not support once the acquisition currency — Chord’s own stock — fell. The economic charge is not the $539.3M; it is the 20,680,000 shares issued at $3,732.1M.

And then the test that puts every return metric in this report in context:

Seventeen years, two commodity super-cycles, one bankruptcy and three transformational mergers have produced $1.0bn of cumulative accounting profit against gross oil and gas property that peaked at $9.46bn in 2019, was written down to $0.81bn in 2020, and stands at $14.85bn today. Eleven years of Oasis earned $600M; 2020 destroyed six times everything the company had ever earned; and five years of the best oil tape in a decade earned $4.1bn, which merely restored the seventeen-year total to break-even-plus.

Method note that must accompany every return figure below. At emergence on 19 November 2020, stockholders’ equity was reset from −$897.2M to +$965.6M and gross oil and gas property from $9,463.0M to $810.6M. The ~$8.65bn of historical capital erased at emergence appears in no denominator of any ROIC or ROE calculation for 2021 onward — including ROIC.ai’s, and including ours. The reported returns are returns on the surviving capital.

Returns on capital.

With a ~2.0 beta, a ~4.3% risk-free rate and a 5% equity risk premium, Chord’s cost of equity is ~14.3%; marginal debt costs 6.00–6.75% pre-tax at a ~15% weight; weighted average cost of capital is ~12–13%. Chord cleared that comfortably in FY2021–FY2023 and has failed it in both years since. On the honest gross-PP&E denominator, FY2025 earned 1.0%, or 3.8% ex-goodwill. On any full-cycle basis this business has not earned its cost of capital, and the three years in which it did coincided exactly with the post-COVID oil spike. That is a price outcome, not a competitive-advantage outcome.

Cash flow and capital intensity.

Free cash flow per share is down 72% from the FY2022 peak — the single most important number in the file for a company whose entire investor pitch is per-share free cash flow. Capital intensity has risen relentlessly: capex was 23% of operating cash flow in FY2021 and 66% in FY2025, and management’s own 2026 budget of ~$1.4bn against FY2025 OCF of $2,041M puts it at ~69% for a flat-production programme. There is no growth capital in that figure. Working-capital quality is clean — FY2025 working-capital changes netted to −$7.2M, so the operating cash flow is not being manufactured on the balance sheet.

Finding, development and the recycle ratio — the second load-bearing finding.

A ~1.0x recycle ratio means the drill bit is running to stand still: the cash margin earned on a barrel roughly equals the cost of finding and developing its replacement, leaving nothing for G&A, interest, tax or the equity. Diamondback’s FY2025 proved-developed F&D was $8.52/Boe against a ~$30/Boe cash margin — a ~3.5x recycle ratio. Chord runs at roughly one-third of that. In fairness to management: FY2024’s headline $68.0/Boe organic F&D is an artefact of a −45.4 MMBoe revision colliding with a partial-year programme (excluding revisions it is $19.6), and FY2025 development costs include $152.1M of non-cash asset-retirement capitalisation, so the cash-only FY2025 figure is ~$14.1/Boe. Neither caveat rescues the three-year 58% organic replacement, which is arithmetic on disclosed reserve quantities. PUD conversion, taken in isolation, is respectable: $520.3M converted 62.5 MMBoe in 2025, or $8.32/Boe, and PUDs at 31% of the proved base are in line with peers, not aggressive.

Balance sheet — the best thing about the company.

Two $750M notes — 6.000% due 1 October 2030 and 6.750% due 15 March 2033 — a $2.75bn borrowing base with $2.0bn of elected commitments maturing 3 November 2029, zero drawn at both 31 December 2025 and 31 March 2026, $32.8M of letters of credit, and ~$2.16bn of liquidity. The 6.375% 2026 notes were retired in March 2025 for $409.1M. There is no maturity before October 2030. Stress-testing at $60 WTI gives ~$1,935M of EBITDA, 0.67x leverage and ~$385M of positive free cash flow. At $50 WTI, EBITDA falls to ~$1,390M, leverage rises to ~0.93x and free cash flow before hedges is ~−$110M, against which the 2026 hedge floors contribute ~$311M — keeping 2026 roughly neutral. In 2027, with only ~13% of oil hedged, the same deck produces a genuine cash shortfall (management would of course cut capital in that world).

The hedge book at 31 March 2026 covers 36.2% of April–December 2026 oil at a weighted average floor/swap of $69.83/Bbl and 12.8% of FY2027, with 2026 collar ceilings between $77.65 and $81.92 and swaps at $69.54. In a ~$85 tape those ceilings are costing money: Q1-2026 realized settlements were −$0.48/Bbl on oil and −$0.32/Mcf on gas. The book is thin enough not to protect the downside and structured tightly enough to cap the upside — an asymmetry that works against shareholders in exactly the environment Chord is currently in.

One liability deserves a flag. Asset retirement obligations stand at $428.8M against 4,415.0 net (10,528 gross) productive wells — ~$97,000 per net well — after a non-cash upward revision of $152.4M in FY2025 alone, a 55% increase in one year. With a 6.2-year proved-developed reserve life and a large legacy well population in a plugging-cost jurisdiction, whether $428.8M discounted is adequate is a live question the disclosure does not answer.

Verdict: economics do not improve with scale. Emphatically not. Per-unit costs did not fall where it matters, per-share economics went backwards while absolute scale grew, returns on capital collapsed as capital was added, the drill bit does not clear its own cost, and the seventeen-year cumulative accounting return is approximately zero. The balance sheet, the crude differential, the cash G&A line and the well-level capital-efficiency trend are all genuinely good. The correct characterisation of FY2021–FY2023 is not “scale worked.” It is “oil was $80.”

7. Capital Allocation

Capital allocation at Chord splits cleanly into three verdicts: disciplined on leverage, procyclical on repurchases, and misaligned in the annual incentive design.

Where the money came from and where it went. Over FY2021–FY2025 Chord generated $4,619M of cumulative free cash flow, paid $2,114.6M of dividends and repurchased $1,300.4M of stock — $3,415.0M returned, or 73.9% of cumulative FCF. In the last two years the payout intensified: FY2024–FY2025 shareholder returns of $1,657.0M consumed 102.9% of the $1,610.9M of free cash flow generated over the same period. Simultaneously, long-term debt rose from $395.9M at the end of 2023 to $1,479.6M at the end of 2025 — +$1,083.7M — while cash acquisitions across those two years totalled $1,230.7M.

The structure is therefore explicit: distributions were funded by operations, and acquisitions were funded by the bond market. The 2030 and 2033 notes are, in substance, the financing for the XTO packages. At 0.58x net leverage that is a defensible choice, and we say so — but it is not the self-funded fortress-balance-sheet story the investor deck implies, and it should be described accurately.

A management claim we cannot reconcile. On the Q4-2025 call, CEO Brown stated: “since 2021, Chord Energy Corporation has returned $6.7 billion of capital to shareholders, which is particularly impressive given it is higher than our current market cap.” The consolidated statements of cash flows for FY2021–FY2025 show $2,114.6M of dividends plus $1,300.4M of repurchases — $3,415.0M, roughly half the cited figure. The gap is not reconcilable from the filings. It plausibly includes distributions by predecessor and acquired entities on a standalone basis (Whiting and/or Enerplus), the Oasis Midstream monetisation, and/or debt reduction — none of which is capital returned by Chord to Chord’s current shareholders. We record management’s statement, we record the filed figure, and we flag the difference rather than adopting either number. Management commentary is a hypothesis; the cash flow statement is evidence.

The M&A record, priced.

The Enerplus deal deserves the fullest accounting because it is the largest capital-allocation decision in Chord’s history. Announced 21 February 2024, it promised “administrative, capital and operational cost synergies of Up To $150 Million Annually with After-Tax Present Value up to $750 Million”; pro forma 2024 free cash flow of $1.2bn at $79 WTI; ~10 years of sub-$60-breakeven inventory, itself up “over 60%”; and — explicitly — that “Post-Combination Return of Capital [is] Expected to Remain at Chord’s Pre-Combination Level of 75%+ of Free Cash Flow.” Against that scorecard:

• Free cash flow: FY2024 actual $918.2M and FY2025 $692.7M, against a $1.2bn pro forma promise, at a realized FY2024 price environment close to the $79 assumption. Missed.
• Production: pro forma combined 4Q23 was 287 MBoepd; FY2025 averaged 276.6 and Q1-2026 275.6 — ~4% below the deal deck two years later, despite ~$1.09bn of subsequent cash acquisitions.
• Inventory: “approximately 10 years” at announcement; “we have been able to maintain 10 years of inventory for the last five years” in May 2026. Unchanged after two years of drilling and one acquisition.
• Return of capital: the 75%+ commitment has been abandoned. Payout ratios by quarter, from management’s own remarks: 92% (Q2-25) → 69% (Q3-25) → ~50% (Q4-25) → ~45% (Q1-26), even as free cash flow rose. Brown, Q1-2026: “we currently do not envision resuming variable dividends and plan to let excess free cash flow go to the balance sheet.”
• Synergies: a bridge against the $150M target has never been disclosed on any of the four calls we read, and no analyst has asked. Management substitutes a self-defined metric — “pro forma free cash flow per share is up more than 35%, all on normalized pricing” — which is non-GAAP, management-constructed and unauditable.

To be fair to management on the last point: cash G&A of $1.00/Boe and the $7M mid-year guidance cut “as the team exceeded synergy expectations” are consistent with real administrative synergy capture, and $160M of run-rate controllable-cost improvement in 2025 is a credible, specific claim. The criticism is not that no synergies were realised. It is that the deal’s own headline promises — FCF, production, inventory, payout — were each missed or abandoned, and the goodwill was fully written off inside 13 months.

The buyback is procyclical on the company’s own numbers. This is the sharpest capital-allocation finding in the file.

Chord bought most heavily at its highest average price on record, then — holding a freshly enlarged $1.0bn authorisation with the shares at a 52-week low — spent $10.0M in an entire quarter at $97.01, leaving $952.2M unused. It then resumed buying as the stock recovered into the $120s and $140s. The stated policy is the opposite: “in the interest of avoiding procyclical buybacks, Chord Energy Corporation may choose to taper repurchases if and when we see higher oil prices more fully reflected in our share price.” The executed pattern is textbook procyclicality. In the company’s defence, Q4-2025 was the quarter in which it closed a $542.2M acquisition funded with new debt, so cash was genuinely committed elsewhere — which is itself a capital-allocation choice: Chord chose to buy XTO’s barrels at ~$60,000 per flowing Boe/d rather than its own at $97.01 per share.

Dividend policy has been structurally reset, not merely varied. Peak-era quarterly ex-dividends ran $4.80 (March 2023) and $3.55 (June 2023), stepping down through $3.25, $2.94, $2.52 and $1.44 to a flat $1.30 base every quarter from March 2025 through May 2026 — six consecutive quarters. Trailing-four-quarter dividends of $5.20 are a 3.70% yield at $140.38, against an 8–10% variable-era yield. (For the record: the Q4-2025 transcript’s reference to a “$0.30” base dividend is a transcription error; the FY2025 10-K states “$1.30 per share per quarter ($5.20 per share annualized)” and the 25 February 2026 declaration was $1.30.) The dividend has been cut 73% from its peak, and management has confirmed the variable component is not returning.

Incentive alignment: the scorecard paid 120% in the goodwill-write-off year. The 2025 annual cash-incentive scorecard, from the proxy filed 19 March 2026:

Three observations. First, there is no return-on-capital metric anywhere in the plan. In a capital-intensive price-taking business, that is the single most consequential design choice, and it is the design that rewards deploying capital rather than earning on it. Second, the one “Profitability” metric — carrying the largest single weight at 21% and paying 142% — is F&D as the proxy itself defines it in footnote 3: “the net operated drilling and completion costs for wells brought to production in 2025 divided by the net expected ultimate recovery of those wells.” That is a company-defined, EUR-denominated construct, not the SEC reserve-based F&D. On the proxy’s definition, F&D performance earned a 142% payout. On the reserve disclosures for the same year, organic reserve replacement over three years was 58% at a ~1.0x recycle ratio with negative revisions in each year. Both numbers are true; only one is paid on, and it is the one whose denominator is a management estimate rather than a booked reserve. Third, 30% of the cash-bonus weight sits on safety and environmental metrics, which paid 193% and 111%.

The net outcome: in a year in which Chord wrote off 100% of the Enerplus goodwill ($539.3M), earned a 2.0% return on common equity and a 1.6% ROIC, and delivered an absolute total shareholder return worse than −10%, the named executive officers were paid 120% of their target cash bonus — the TSR modifier reducing the outcome only from 133%. The qualitative 20% paid 161%, credited in part for “the positive impact of the successful XTO acquisition” and “substantial increase in inventory depth and quality.”

The long-term plan is materially better and should be credited: 67% of the CEO’s equity (60% for other NEOs) is TSR-linked, split 17% absolute-TSR PSUs (0–300% of target) and 50% relative-TSR PSUs (0–200%), with 33% time-vested. CEO total compensation was $8.57M in 2025 and $8.18M in 2024, against $2.99M in 2023 — though the 2023 figure carries only $1.0M of stock awards versus ~$6.1M in each subsequent year, which looks like a grant-timing convention rather than a genuine tripling of pay, and we do not present it as the latter.

Insider behaviour. Across 181 Form 4 filings and 249 transaction rows over five years, there have been five open-market purchases totalling 3,875 shares: director Brooks (625 at $118.75 and 500 at $123.76 in late 2021; 1,000 at $123.00 in August 2022) and director Holroyd (500 at $149.51 in August 2024; 1,250 at $85.50 on 7 November 2025). The Holroyd purchase is the only insider buy anywhere near the November 2025 low, and it is a ~$107,000 ticket. Against that, 2026 has seen consistent distribution into the rally: EVP Michael Lou sold 14,503 shares at $125.44 and 497 at $126.28 on 12 March (not plan-flagged) and 10,000 at $140.42 on 23 July (10b5-1); CFO Robuck 5,000 at $121.75; COO Henke 1,276 at $145.97; and director Brooks 10,126 shares between $120.28 and $138.57. The dollar amounts are small and much of the activity is routine post-vest liquidation, so this is a soft signal. But it points the same direction as the buyback timing: no accumulation at $85–100 in late 2025, consistent distribution at $114–146 through 2026, and the single largest executive sale of the year struck at $140.42 — within 1% of the price at which this report is written.

Verdict: mixed, tilting negative. Balance-sheet management has been genuinely excellent — the refinancing execution, the borrowing-base maintenance and the 2030 maturity wall are all first-rate, and the decision not to chase a 2.4-sigma oil move with a rig programme is real discipline that peers have historically failed. Against that: two of the three largest acquisitions have not earned their cost, the Enerplus goodwill was fully written off in 13 months, the deal’s own headline promises were missed or abandoned, the buyback executed exactly backwards, the variable dividend and the 75%-payout commitment are gone, and the annual incentive plan contains no return-on-capital gate while paying 120% in the write-off year. Management has allocated capital defensively but not intelligently.

8. Changes and Headwinds — Last Two Years

The two structural changes that matter. First, the capital-return framework has been rebuilt downward. The variable dividend — which, as Section 10 and the event map show, was the historical return — is gone, replaced by a flat $1.30 base plus opportunistic repurchases, with excess free cash flow now directed to the balance sheet. The payout ratio has fallen through four consecutive quarters (92% → 69% → ~50% → ~45%) while free cash flow rose. Management’s rationale is anti-procyclicality and de-levering, and at 0.58x leverage the de-levering rationale is thin. The honest reading is that Chord has decided its shares are a better use of marginal cash than a variable dividend, and then declined to buy many of them.

Second, the acquisition engine has produced two consecutive disappointments. Enerplus wrote off its goodwill in 13 months; XTO produced no sequential volume growth in the quarter after closing. Management remains explicitly acquisitive — “we are sort of inquisitive and acquisitive by nature. We’ve done 5 deals over the last 5 years… But importantly, that consolidation can’t just make us bigger. It has to make us better, too” — and confirmed on the Q1-2026 call that it would be “quite competitive on any package that comes to market.” When Jefferies asked directly what leverage the company would stretch to for a large deal, management did not answer. Given the record, an unanswered question about acquisition leverage capacity is itself a risk factor.

The headwind that dominates everything else is the one Chord does not control. The Q1-2026 call captured it precisely: management planned 2026 at $64 WTI in February and was answering questions about ~$100 oil in May, having changed neither the capital budget nor the hedge book materially. The free cash flow guide doubled from ~$700M to ~$1.4bn on the same programme. That is the definition of a price-taker, and it cuts symmetrically — the June ceasefire took the premium straight back out.

A material limitation to disclose. Chord reports Q2-2026 results on 5 August 2026, four days after this report date. Every forward figure here is struck on Q1-2026 disclosure plus the 6 May 2026 guidance update. A news sweep through 1 August 2026 surfaced nothing material beyond the earnings-date notice, routine 13F aggregator items and sell-side previews.

Verdict: on balance these developments weaken the thesis. The two largest corporate actions of the period were an acquisition whose goodwill was fully written off within 13 months and a bolt-on that produced no sequential growth. The genuinely strengthening developments are operational (the 4-mile program) and financial (a maturity ladder with nothing due before October 2030) — neither of which offsets a capital-return framework that has been reset downward twice.

9. Risk Analysis

The risk that is not on the list, and should be. Chord’s diversifiable risks are modest — the balance sheet is strong, the jurisdiction is friendly, the reserve report is independently prepared and PUD discipline is adequate. The undiversifiable risk is that the business does not earn its cost of capital across a cycle. That is not an event risk; it is the base case implied by a 1.6% ROIC, a ~1.0x recycle ratio and a seventeen-year cumulative accounting profit of $1.0bn. A risk matrix cannot capture it because it is not a tail — it is the distribution’s centre.

10. Valuation Discussion

No price target and no recommendation appear in this section. What follows is an embedded-expectations analysis: what the current price requires to be true.

Inputs. Price $140.38 (close, 31 July 2026); 56,299,183 shares outstanding (Q1-2026 cover page, 4 May 2026) → market capitalisation $7,903.5M; net debt $1,254.7M (31 March 2026) → enterprise value $9,158.2M; face debt $1,500.0M; FY2025 adjusted EBITDA $2,236M; FY2025 PV-10 $9,072.4M at an SEC deck of $65.34/Bbl and $3.39/MMBtu; book value per share $142.92.

A reconciliation the reader needs. ROIC.ai reports EV/TTM EBITDA of 5.53x on GAAP TTM EBITDA of $1,697.2M to 31 March 2026. That TTM window contains the $539.3M goodwill impairment; adding it back gives $2,236.5M, which ties to the company’s adjusted EBITDA. The 5.53x and our 4.10x differ only by the impairment add-back and the price date. We use the adjusted basis and say so.

The 2026 move is multiple, not earnings. Dividing ROIC.ai’s enterprise value at successive dates by a constant FY2025 adjusted EBITDA of $2,236M:

The multiple expanded ~37% since year-end 2025 on an unchanged EBITDA base. The entire 2026 advance is re-rating, and the re-rating moved with an oil factor that is now 2.43 standard deviations extended over 126 days.

Embedded expectations. The cleanest available anchor is management’s own two-point sensitivity, given one quarter apart on the same capital programme: ~$700M of 2026 free cash flow at $64 WTI and $3.75 gas (Q4-2025 call), and ~$1.4bn at $80 WTI and $3.25 gas (Q1-2026 call). That implies ~$43.75M of free cash flow per $1/Bbl of WTI. Against the $7,903.5M market capitalisation:

At $140.38 the market is capitalising something close to a mid-$60s-to-$70 WTI world at 8–12x free cash flow. It is emphatically not extrapolating the ~$84–85 strip, let alone the March spike. CEO Brown said as much on 6 May 2026: “If you look at the headline oil price, our stock is not underwriting anywhere near that level.” He is right on the arithmetic, and it is the strongest single argument for the shares.

The question the arithmetic leaves open is the one that matters: should a business earning a 1.6% ROIC (6.1% ex-goodwill), replacing 58% of its production organically at a ~1.0x recycle ratio, on a 9.1-year reserve life and a shortening PDP life, be capitalised at a $70-oil world rather than a $65-oil one? A $10/Bbl error in that judgement is ~$438M of annual free cash flow — 5.5% of the market capitalisation per dollar of WTI.

Scenario analysis.

The PV-10 anchor. Enterprise value at 1.01x PV-10 on the $65.34 deck means the market ascribes essentially nothing to unbooked inventory at that price. The 10-K’s own sensitivity is ±$1.8bn of PV-10 (roughly ∓20%) for a ∓10% move in the deck, so PV-10 is approximately 2x-levered to the price assumption. At a ~$72 deck, PV-10 would be ~$10.9bn and EV/PV-10 ~0.84x; at a ~$59 deck, ~$7.3bn and ~1.26x. This is the cleanest way to see why the equity is so sensitive: both the numerator and the denominator move with crude, and the denominator moves twice as fast.

Earnings-power value versus asset value (Greenwald). Price/book of 0.98x sits on a book that was reset upward at fresh-start in November 2020 and has since absorbed a $539.3M goodwill charge — an asset value that is neither a replacement cost nor a liquidation value, and should not be treated as a floor. The earnings-power calculation is more honest: at $70 WTI, ~$963M of sustainable free cash flow capitalised at the ~12–13% cost of capital derived in Section 6 gives ~$7.4–8.0bn of equity value before any terminal credit for a 9.1-year reserve life — which brackets the current $7.9bn market capitalisation almost exactly. On mid-cycle economics and its own cost of capital, Chord is approximately fairly priced. It is neither the bargain the 4.1x headline implies nor an obvious short.

Peer context. Peer multiples below were struck on dates spread across June–July 2026, a window over which crude moved materially, so treat them as ordinal rather than cardinal: SM ~3.5–3.6x, Ovintiv ~4.0–4.2x, Chord 4.10x, Permian Resources ~5.0–5.5x, Devon ~5.0–5.5x, Diamondback ~6.0–7.3x EV/EBITDA. Chord sits in the cheap half. The discount is deserved, not anomalous. Diamondback’s ~2.4-turn premium is bought with a $5.55 lifting cost, a ~75% field cash margin and a ~3.5x recycle ratio, against Chord’s $9.73, 59.8% and ~1.0x. Cheapness that is fully explained by inferior unit economics is not a variant perception.

Own-history context. The AZI valuation index at 24 July 2026 shows P/S at the 82.1st percentile of Chord’s own multi-year range against P/B at the 37.7th, with the composite of 59.9 resting on only two components (P/E is correctly null on negative trailing EPS). Read the split rather than the composite: the market is paying a full price on the revenue line while discounting the stated book value — which is the right instinct for a book that was reset in 2020 and impaired in 2025, and a further reason to distrust any revenue-based multiple on this company given the purchased-volume gross-up.

What cannot be used, and why. GAAP P/E is meaningless (trailing EPS of −$1.07 on the goodwill charge; an 81.7% FY2025 effective tax rate; a negative 15.2% Q1-2026 rate driven by an out-of-period error correction). EV/Sales is meaningless (the purchased gross-up was 27.0% of FY2024 total revenue at a 0.18–0.50% margin, and quadrupled again in Q1-2026). Adjusted EPS is not comparable to GAAP (a $2.66 per share, 58% gap in Q1-2026). Operating-cash-flow multiples require adjustment for hedge settlements classified in investing.

11. Variant Perception

What consensus believes. The sell-side rates Chord a “Moderate Buy” — 9 buy and 4 hold of 13 covering firms, per a January 2026 aggregation — and Zacks upgraded it to Rank #1 (Strong Buy) on 16 April 2026, with repeated “Strong Momentum Stock” and “undervalued” pieces through the second quarter. Short interest was 4,394,786 shares at the 13 March 2026 settlement, up 20.9% month over month and ~7.8% of shares outstanding — though that is a stale, secondary-sourced aggregator figure and should be treated as directional only. Sentiment is not contrarian. The tape is loudly bullish.

The consensus case, fairly stated, has four legs: (i) the cheapest large Bakken pure-play, at ~4x EBITDA and ~1x PV-10; (ii) the best balance sheet in the peer group, with no maturity to 2030; (iii) a self-improving cost story led by 3- and 4-mile laterals with an $8–12/Bbl cost-of-supply prize; and (iv) a disciplined management team that refused to chase a $100 oil print with a rig programme.

Where we agree. Legs (ii) and (iv) are correct and well evidenced. Leg (i) is arithmetically correct. Leg (iii) is correct at the well level — a 37% reduction in drilling-and-completion cost per foot over four years is real, the Rystedt outperformed its type curve by 30%, and the first full four-mile pad cleaned out to total depth on all five wells.

The variant perception, stated precisely. The cost-down is real at the well level and has not appeared at the corporate level, and the market is pricing the well-level story as though it were the corporate one. Five years of well-level improvement, two mergers, three rounds of synergy claims and a 4.8x volume increase have produced lease operating expense per barrel that is higher than it was in 2021. Every dollar of well-level saving has so far been consumed by the cost of operating an older, larger, higher-water-cut well base — which is exactly what “the Bakken has more fixed cost” means when it shows up in the accounts rather than the slide deck. Until LOE/Boe actually falls, the corporate cost-of-supply improvement is a hypothesis, and it is the hypothesis that the inventory count, the PUD book and the equity’s terminal value all rest on.

The second variant element is the return decomposition. Consensus points to a +143% five-year total return as evidence of a good holding. The dividends were the return: over three years the share price is −10.8% and the total return is +4.8%, so the entire three-year positive return is the dividend — and that dividend is 73% smaller and, per management in May 2026, is not going back up. Over the whole post-relisting window Chord paid $66.03/share of dividends against a $31.00 starting price. That record cannot be extrapolated, because the policy that produced it has been formally retired.

The third element is what the factor model says about the 2026 move. Despite the momentum framing in the financial press, the Momentum factor loading is zeroed in three of four model specifications and mildly negative in the fourth. The model attributes Chord’s return to OilPrice (+1.99), Energy sector (+1.30), Market (+0.69), DividendYield (+0.84) and Value (+0.28) — a commodity-beta and value rally, not a crowded momentum trade. Quality is zeroed for Chord while Devon, ConocoPhillips, SM, Matador, Permian Resources and Diamondback all carry small positive Quality loadings. And the regime split is the sharpest evidence available that consensus may be offside somewhere: the OilPrice factor is +22.0% over 126 days (z +2.43, extreme) while the Oil & Gas E&P industry factor is −26.4% over 252 days (z −2.16, extreme). The market is paying for barrels and not for the companies that produce them. Whether that resolves by the equities catching up or by the commodity giving back is not knowable; what is knowable is that Chord carries a +1.99 loading on the extended leg.

The five assumptions that actually matter.

1. WTI averages $70 or better through 2027–2028 (only 36% of remaining-2026 and ~13% of 2027 oil is hedged).
2. The fourth mile contributes at or near 100%, converting the $8–12/Bbl cost-of-supply claim into the ~$5/Bbl corporate improvement management has sketched.
3. Sub-$60-breakeven inventory genuinely holds at ~10 years without further acquisition — i.e. the cost-driven reclassification mechanism does not reverse.
4. LOE/Boe finally breaks below ~$9.00 rather than continuing to drift upward.
5. Management does not fund another large acquisition at a ~1.0x recycle ratio, particularly with equity.

The strongest bull case is that Chord is a cheap option on Williston consolidation with a fortress balance sheet, whose 4-mile program is a genuine, basin-specific and hard-to-replicate cost innovation arriving precisely as a two-year capital drought in E&P equities sets up the supply-side conditions Marathon’s capital-cycle framework rewards — and that at ~1.0x PV-10 you are paying nothing for any of it.

The strongest bear case is that this is a high-cost operator in a late-life basin, whose reserve life is shortening while it buys reserves, whose drill bit does not clear its own cost, whose seventeen-year cumulative accounting profit is ~$1.0bn on ~$14.9bn of gross property, and whose 2026 share-price move is a rented geopolitical premium that mechanically reverses — as it did, by 25%, in six weeks in June.

Falsification. Bull case falsified if LOE/Boe exceeds ~$10.00 for two consecutive quarters while 4-mile TILs are ramping, or if FY2026 reserve revisions are again materially negative. Bear case falsified if organic reserve replacement exceeds 100% in a year without acquisitions and the fourth-mile toe assumption is formally raised toward 100% on produced data.

12. Fact vs. Interpretation

13. Open Questions

1. Is the $428.8M asset-retirement obligation adequate? ~$97,000 per net well across 4,415.0 net (10,528 gross) wells, after a +$152.4M non-cash upward revision in FY2025 alone (+55% in one year), against a 6.2-year proved-developed reserve life in a basin with a large legacy well population. If the FY2025 revision indicates prior estimates were systematically low, further upward revisions would run through capitalised property and, ultimately, DD&A.
2. What actually reconciles the “$6.7 billion returned since 2021” claim to the $3,415.0M in the cash flow statements? Predecessor-entity distributions, the Oasis Midstream monetisation, and debt reduction are the candidates. None of them is capital returned by Chord to Chord’s current shareholders.
3. Were the Enerplus synergies delivered against the announced $150M annual target? No bridge has been given on any of four earnings calls, and no analyst has asked. Management substitutes a self-defined “pro forma FCF per share up more than 35% on normalized pricing” construct that cannot be audited.
4. What is the Marcellus worth, and when will it be sold? Non-core for four consecutive quarters, realizing $6.40/Mcf against a $3.14 blended price, with no disclosed carrying value, no process and no timetable. An unpriced sum-of-the-parts stub.
5. Why did the purchased-oil-and-gas gross-up quadruple in Q1-2026 — from $111.6M to $515.0M — with no accompanying disclosure, for an activity earning a 0.2–0.5% margin? Does it introduce counterparty, inventory or margin-call exposure disproportionate to ~$5M of annual gross profit?
6. What leverage would management accept for a large Williston package? Asked directly by Jefferies on the Q1-2026 call; not answered. Given a five-deals-in-five-years cadence and an impaired goodwill balance, this is the most consequential unanswered question in the file.
7. Will the fourth-mile toe contribution be formally re-underwritten from 80% toward 100%, and on what evidence base? Management has explicitly telegraphed the possibility. It is simultaneously the largest identified upside and the largest assumption embedded in the inventory count.
8. How much of the ~10-year inventory would survive a $9.75+ LOE and a $60 strip? The reclassification mechanism management describes works in both directions and has never been sensitised publicly.

14. What Must Be True

For the bull case to be right, all of the following must hold:

1. WTI averages $70 or better through 2027–2028. At $64 the company generates ~$700M of free cash flow against a ~$1.4bn maintenance budget and a $293M base dividend; the equity’s entire valuation support rests on the upper half of that range. — Falsification test: two consecutive quarters of WTI below $65 with 2027 hedge coverage under 15%.
2. The 4-mile program converts into a corporate cost-down. The $8–12/Bbl cost-of-supply claim must show up in consolidated lease operating and DD&A per barrel, not just in the well file. — Falsification test: LOE/Boe at or above ~$10.00 for two consecutive quarters while 4-mile turn-in-lines are ramping toward 40% of the programme.
3. The sub-$60-breakeven inventory holds at ~10 years without further acquisition. — Falsification test: an inventory-runway reduction disclosed in the FY2026 10-K, or a further materially negative reserve revision, absent a corresponding cost improvement.
4. Capital allocation improves. No further large, equity-funded acquisition at a ~1.0x recycle ratio; repurchases executed counter-cyclically rather than at the highs. — Falsification test: an announced deal above ~$1bn with an equity component, or another quarter in which repurchases are suspended near a 52-week low with authorisation outstanding.

For the bear case to be right, all of the following must hold:

1. The cost structure remains structurally high. Lifting cost stays at or above ~$9.50/Boe, keeping the field cash margin the thinnest in the peer group and the operating leverage the highest. — Falsification test: LOE/Boe below $9.00 for two consecutive quarters.
2. The drill bit continues not to clear its own cost. Organic reserve replacement stays materially below 100% and the recycle ratio near 1.0x, so reserve growth continues to require cash acquisitions. — Falsification test: organic replacement above 100% in a year with no acquisitions.
3. The 4-mile uplift disappoints or is slow to prove. Toe contribution stays at 80%, or EUR uplift lands materially below the 90–100% claim as the sample grows beyond 12 producing wells. — Falsification test: a formal re-underwriting of the fourth mile from 80% toward 100% on produced data, as management did for the third mile.
4. Oil mean-reverts toward the $60s as the Iran premium unwinds, taking the multiple back toward the ~3.0x at which Chord traded as recently as December 2025. — Falsification test: a durable supply-side regime shift — sustained OPEC+ discipline or a structural non-OPEC supply response — that holds WTI above $80 for four consecutive quarters.

The single most informative disclosure to watch is neither the oil price nor the earnings beat. It is lease operating expense per barrel of oil equivalent, reported quarterly. It is the one line that adjudicates simultaneously the moat question, the inventory question, the 4-mile question and the terminal-value question — and it has not moved in five years.

15. Source Appendix

The full source appendix, listing every primary filing, transcript, data feed and third-party source relied upon, together with access dates, is provided as Appendix B to this report.

Principal primary sources: Chord Energy Forms 10-K for FY2021 (Oasis Petroleum predecessor), FY2022, FY2023, FY2024 and FY2025; Form 10-Q for Q1-2026 and Q2-2025; DEF 14A proxy statements 2022–2026; the Enerplus arrangement press release of 21 February 2024 and associated S-4/DEFM14A; the Form 4 corpus for CIK 0001486159 (181 filings, 2021–2026); and earnings-call transcripts for Q2-2025 through Q1-2026.

Principal data sources: SEC EDGAR XBRL company facts; the AZI daily price and valuation-index feeds; the ROIC.ai enterprise-value, ratio and transcript tools; and the FactorsToday factor model (loadings, leaderboard, factor returns, related stocks).

Peer companies used for benchmarking, from their own FY2025 Form 10-K and quarterly disclosures: APA Corporation, EOG Resources, ConocoPhillips, Diamondback Energy, Devon Energy, Permian Resources, Ovintiv and SM Energy.

Sections 1–15 of this article contain no investment recommendation and no price target. The Claude's Take block at the head of the piece is a clearly-labelled, subjective opinion offered as general information and commentary — not investment advice, and not a recommendation to buy or sell any security. The author holds no position in any security mentioned.

APPENDIX A — Standard Diligence Questionnaire

Chord Energy Corporation (NASDAQ: CHRD) · 1 August 2026

Supplemental to the analysis above. Fact / Interpretation / Assumption labels are applied where the distinction matters.

General

What thoughtful questions have other investors asked about this company?

The sell-side’s questions are unusually well-focused, and reading four consecutive calls (Q2-2025 through Q1-2026) makes the hierarchy plain. Ranked by frequency and persistence:

1. The 4-mile lateral program — asked on every call by multiple analysts (TPH, RBC, Wolfe, Citi, Pickering, Texas Capital, BofA, Roth, Daniel Energy, Scotiabank). Specifically: toe contribution, EUR uplift versus the 90–100% claim, cost per foot, and whether the 80% fourth-mile underwriting will be raised. This is unambiguously the stock’s swing factor in the market’s view, and we agree with that assessment.
2. Inventory depth, and where the organic additions come from. William Blair’s Dingmann extracted the single most useful disclosure of the four calls by asking what dictates the breakeven — establishing that the “~10 years” is screened at sub-$60 WTI, not a total-locations count.
3. The capital-return mix — base dividend versus buyback versus variable dividend versus debt paydown. Scotiabank’s Paul Cheng pressed twice on tying dividend growth to per-share production growth and was deflected: “I understand the math behind that, Paul… it’s just — it’s a capital allocation decision.”
4. Whether ~$100 oil would trigger more activity (Q1-2026) — management said no.
5. Marcellus monetisation — asked repeatedly, answered identically each time.

The more revealing list is what management would not answer: 2027 guidance (deflected on three separate calls); the incremental economic lateral footage from a 4-mile shift (“I can’t quantify that for you, Oliver”); AI/ML cost savings (“To quantify that at this point, I think it’s pretty tough”); the infill/refrac opportunity (“We really have not quantified that yet”); the deeper Three Forks column (“we are watching what others do”); and — most consequentially — what leverage the company would stretch to for a large Bakken acquisition (Jefferies, Q1-2026; not answered).

The question no one has asked, across all four calls, is whether the $150M annual synergy target announced with the Enerplus transaction in February 2024 was delivered. Management has never provided a bridge, substituting a self-defined “pro forma FCF per share up more than 35% on normalized pricing” metric. For a $4.6bn acquisition whose goodwill was fully impaired within 13 months, that is a striking gap in the diligence record.

Cyclicality and Earnings Nature

Are earnings at a cyclical high or low?

Neither — they are at a cyclical middle on a structurally declining per-unit base, which is the more interesting answer. FY2025 adjusted EBITDA of $2,236M is essentially flat against FY2022’s $2,012M and FY2024’s $2,231M, but that stability masks a 4.8x volume increase offsetting a collapse in per-barrel economics: realized revenue fell from $68.07 to $38.60 per Boe and field cash margin from $49.44 to $23.09. Free cash flow per share, the metric that strips out the volume growth, fell 72% from its FY2022 peak. Fact. The current quarter benefits from a geopolitical spike — WTI above $100 in March 2026 — that had substantially reversed and partly re-established by late July. Interpretation: current earnings are above a normalised mid-cycle level on price and below the five-year record on per-unit economics.

Driven by the external environment or internal actions?

Overwhelmingly external. The decomposition is unusually clean: between FY2022 and FY2025, realized revenue per Boe fell $29.47 while cash field costs fell $3.13. Eighty-nine percent of the margin change was price; internal action offset eleven percent of it. Fact (computed from disclosed per-Boe data). The clearest single illustration: management planned 2026 at $64 WTI in February and was fielding questions about ~$100 oil in May, with the free cash flow guide doubling from ~$700M to ~$1.4bn on an unchanged capital programme.

How stable are revenues?

Not stable in any meaningful sense, and less stable than the headline suggests because “total revenue” contains a zero-margin gross-up (27.0% of FY2024 revenue at a 0.18–0.50% margin). On the clean line — oil, NGL and gas revenue — the five-year series is $1,200M → $2,976M → $3,132M → $3,836M → $3,897M, which looks like growth but is volume growth against falling prices. There are no contracts, no backlog, no take-or-pay and no recurring-revenue construct. The only structural recurrence is decline: ~5,000 operated wells that deplete annually and must be replaced with ~$1.4bn of capital.

Outlook for products/services?

The product is crude oil, NGLs and natural gas sold at spot-referenced prices. Chord’s oil realizes within ~3.2% of WTI (good); its NGLs realize ~9% of WTI and its gas ~32% of Henry Hub (structurally poor, and 44% of the Boe stream).

How big will this market be — growing, shrinking, domestic or international?

Global crude demand is the relevant market and Chord is a price-taker within it. The company’s own market — Williston Basin production — is mature: Chord’s total reserve life shortened from 10.4 to 9.1 years and its PDP life from 7.3 to 6.2 years over a single year in which it purchased 38 MMBoe of reserves. Fact. Interpretation: the basin is in the consolidation phase of its life cycle, which is precisely the phase in which the marginal buyer of assets is most at risk of overpaying — and Chord has done five deals in five years, most recently buying from a seller (ExxonMobil) with no shortage of alternatives.

Business Quality and Competitive Moat

Is the industry getting more or less competitive?

Less competitive at the corporate level (consolidation is reducing the operator count in the Williston) and no less competitive economically, because consolidation in a price-taking commodity industry does not create pricing power. It creates operating scale, which Chord has, and which has not lowered its lifting cost.

How profitable is the business (ROIC, ROE)?

Poorly, and deteriorating. ROIC fell 49.7% → 27.2% → 19.0% → 8.9% → 1.6% across FY2021–FY2025 (6.1% adding back the goodwill impairment). On NOPAT over gross oil and gas property — the denominator that gives no credit for depletion already expensed — FY2025 earned 1.0%, or 3.8% ex-goodwill. Return on common equity was 2.0% in FY2025 against 216.4% in FY2022. Weighted average cost of capital is ~12–13%. The company cleared its cost of capital in FY2021–FY2023 and failed it in FY2024 and FY2025. Fact (computed and cross-checked against ROIC.ai, which brackets our figures).

The mandatory caveat: every one of those returns is computed on a balance sheet from which ~$8.65bn of gross oil and gas property was erased at fresh-start on 19 November 2020. They are returns on the surviving capital, not on the capital invested. Across the full seventeen-year history of the registrant (2009–2025), cumulative GAAP net income is +$1,002.1M — $600M earned by Oasis over eleven years, $3,690M destroyed in 2020, and $4,093M earned back across the five best oil years in a decade.

How profitable is the industry — how many competitors, what barriers to entry?

Barriers to entry in US onshore E&P are essentially capital and acreage, both of which are purchasable. There is no regulatory licence limiting entry, no technology monopoly, and no customer relationship to defend. The competitor set in the Williston has consolidated (Chord, Devon via the Marathon/Grayson Mill assets, Continental, Hess/Chevron, Kraken and a long tail), but Chord’s factor-similar peer set is the entire E&P complex: its cosine similarity to the XOP ETF is 0.9836. Interpretation: statistically the market cannot distinguish Chord from the generic E&P basket, which is the strongest available evidence against a differentiation claim.

Can the business be easily understood?

Yes, with one exception. The operating model is transparent: drill Middle Bakken and Three Forks wells, produce them, replace decline with ~$1.4bn a year. The exception is the accounting, which requires four separate adjustments before the numbers are usable — stripping the purchased-volume gross-up from revenue, normalising derivative marks out of GAAP earnings, adding back hedge settlements misclassified into investing cash flow, and removing a $41.8M out-of-period tax correction from Q1-2026 net income. A business this simple should not require four adjustments to read.

Can it be undermined by foreign low-cost labour?

Not by labour, but by low-cost foreign production, which is the same threat in a different form and is the dominant risk in the file. OPEC+ spare capacity is the marginal supply that sets the price at which Chord’s ~$9.73/Boe lifting cost is economic. Management itself framed this on the Q1-2026 call as the reason not to grow: “we have seen significant behind-choke volumes in the global market that could come to market at any time.”

Do brands matter?

No. A barrel of Williston crude is fungible.

What is the nature of competition?

Competition for assets (acquisition auctions), for services (rigs, frac crews, sand, labour) and for capital (investor allocation across E&Ps). Competition for customers does not exist. Chord competes in the first category as a buyer — five times in five years — which means the competitive dynamic that most affects shareholders is the price Chord pays, not the price it receives.

Customers’ switching costs?

Zero. There are none.

Financial Condition and Balance Sheet

Assets not fully recognised on the balance sheet?

Yes, three of them, and they matter in different directions. (i) Undeveloped inventory beyond the PUD book — management’s ~10 years of sub-$60-breakeven locations, of which only 288.0 MMBoe are booked as PUDs. Enterprise value at 1.01x PV-10 on the $65.34 SEC deck means the market currently ascribes essentially nothing to it. (ii) The Marcellus non-operated interest, carried without separate disclosure, realizing $6.40/Mcf against a $3.14 blended price, described as non-core for four consecutive quarters. (iii) The deeper Three Forks benches, explicitly excluded from the inventory count and unquantified by management.

Off-balance-sheet liabilities?

Nothing exotic. $32.8M of letters of credit; operating and finance leases disclosed conventionally; firm transportation and gathering commitments in the ordinary course. The item that deserves scrutiny is on-balance-sheet but arguably understated: asset retirement obligations of $428.8M against 4,415.0 net (10,528 gross) productive wells — ~$97,000 per net well — following a non-cash upward revision of $152.4M in FY2025 alone, a 55% increase in one year. With a 6.2-year PDP life, whether that discounted liability is adequate is a live open question the disclosure does not resolve.

How conservative is the accounting?

Mixed, with three specific reservations and two credits.

Reservations. (1) Hedge settlements are classified in investing rather than operating cash flow, which flattered FY2023 reported operating cash flow by $268.9M — 17% — relative to peers using the conventional presentation. Disclosed and permissible; still flattering. (2) A self-identified prior-period error in the FY2025 tax provision relating to goodwill-impairment deferred taxes was corrected through Q1-2026 as a $41.8M benefit rather than by restatement, and deemed immaterial; it represents 38% of the quarter’s reported net income. (3) The purchased-volume gross-up quadrupled in Q1-2026 to $515.0M with no accompanying disclosure, for an activity earning ~0.2–0.5%.

Credits. Reserves are prepared by NSAI, an independent engineer. PUD discipline is adequate — 62.5 MMBoe converted in 2025 at $8.32/Boe, PUDs at 31% of the proved base, and a stated intent to develop all PUDs within five years. Working capital is clean: FY2025 changes netted to −$7.2M, so operating cash flow is not being manufactured on the balance sheet. And the FY2025 goodwill impairment was taken promptly and in full rather than staged — an unflattering charge recognised without delay.

How CapEx-hungry is the business?

Extremely, and increasingly. Capital expenditure rose from 23.3% of operating cash flow in FY2021 to 66.1% in FY2025; the 2026 budget of ~$1.35–1.45bn is ~69% of FY2025 operating cash flow. Critically, by management’s own description this is entirely maintenance capital — “a low to no oil growth program” delivering 157–161 MBopd. There is no growth capital in the budget. Every barrel of volume growth since 2021 was acquired, not drilled.

Capital Allocation and Management

How much FCF does the business generate, how does management use it, what is the philosophy?

FY2025 free cash flow was $692.7M ($11.97 per share, down 72% from FY2022’s $43.18). Management guides ~$700M for 2026 at $64 WTI and ~$1.4bn at $80. The stated waterfall was: base dividend first, then buybacks, then variable dividends for anything incremental. That waterfall was formally amended in May 2026: variable dividends are shelved and excess free cash flow now goes to the balance sheet. The realised payout ratio has fallen through four consecutive quarters — 92% → 69% → ~50% → ~45% — even as free cash flow rose, and against a February 2024 commitment that post-combination return of capital would “remain at Chord’s pre-combination level of 75%+ of free cash flow.”

Significant acquisitions recently?

Three, totalling well over $5bn of consideration in four years: Whiting (all-stock merger of equals, July 2022), Enerplus ($4,611.3M, May 2024 — 20.68M shares at $3,732.1M plus cash; contributed $81.7M of stub-period pre-tax income; goodwill 100% impaired within 13 months), and the XTO Williston package ($542.2M cash, October 2025 — ~9,000 Boe/d at ~$60k per flowing Boe/d, and no sequential production growth in the quarter after closing). Management remains explicitly acquisitive and declined to state a leverage ceiling for a large deal when asked.

Buying back shares?

Yes, and procyclically. FY2024: 3,114,007 shares at a weighted average $142.20 ($442.8M). FY2025: 3,491,618 shares at $104.39 ($364.5M). Q4-2025: 103,057 shares at $97.01 — $10.0M for the entire quarter — with the stock at a 52-week low of $84.25 and $952.2M of a freshly enlarged $1.0bn authorisation unused. Q1-2026: $67.7M as the stock recovered into the $120s–$140s. Share count has fallen 9.0% from 61,879,575 (1 August 2024) to 56,299,183 (4 May 2026), recovering a fraction of the 180% increase in weighted diluted shares between FY2021 and FY2025.

Issuing large amounts of new shares to insiders?

No. Equity-based compensation is a normal-scale programme (108 grant transactions across 181 Form 4s in five years, with 51 tax-withholding dispositions). The dilution in this story came from acquisitions, not from compensation.

Compensation policy of directors/management?

CEO Daniel Brown’s total compensation was $8.57M (2025) and $8.18M (2024). The long-term plan is well designed: 67% of the CEO’s equity and 60% for other named executives is TSR-linked (17% absolute-TSR PSUs paying 0–300%, 50% relative-TSR PSUs paying 0–200%, 33% time-vested RSUs over three years).

The annual cash plan is not well designed. The 2025 scorecard weights Safety at 19% (paid 193%), Environment at 11% (paid 111%), EBITDAX at 18% (89%), expense management at 19% (128%), capital expenditure at 13% (130%) and F&D at 21% (142%), with a 20% qualitative component that paid 161%. There is no return-on-capital metric anywhere in the plan. The single “Profitability” metric is F&D as the proxy defines it — “net operated drilling and completion costs for wells brought to production in 2025 divided by the net expected ultimate recovery of those wells” — a company-defined, EUR-denominated construct rather than the SEC reserve-based measure. On that definition F&D paid 142%; on the reserve disclosures, three-year organic replacement was 58% at a ~1.0x recycle ratio with negative revisions each year.

Net outcome: in the year Chord wrote off 100% of the Enerplus goodwill ($539.3M), earned a 2.0% return on equity and delivered an absolute TSR worse than −10%, the executive team was paid 120% of target cash bonus — the TSR modifier reducing the score only from 133% to 120%.

Motivations of management?

The equity plan aligns them with total shareholder return over three years, which is genuine. The cash plan rewards production, cost per barrel, capital spent and an EUR-denominated F&D — a design that rewards deploying capital efficiently rather than earning a return on it. Interpretation: this is a management team incentivised to be an excellent operator and an active consolidator, and not incentivised to say no to a deal. The record is consistent with that: five acquisitions in five years, an impaired goodwill balance, and a buyback that shut off at the bottom.

Insider behaviour points the same way. Five open-market purchases in five years totalling 3,875 shares — the largest being a director’s 1,250 shares at $85.50 in November 2025 — against consistent 2026 selling at $113–146, including the CFO at $121.75, the COO at $145.97, and an EVP selling 10,000 shares at $140.42 on 23 July 2026, within 1% of the price at which this report is struck.

Valuation and Market Data

Is the stock an ADR, MLP, or K-1 issuer?

No. Chord Energy Corporation is a Delaware C-corporation listed on Nasdaq issuing a Form 1099. There is no K-1 and no ADR structure. (Its predecessor’s midstream affiliate, Oasis Midstream Partners, was an MLP, but it was sold to Crestwood in 2022 and is no longer part of the structure.)

Dividend policy?

A flat base cash dividend of $1.30 per share per quarter ($5.20 annualised), paid for six consecutive quarters from March 2025 through May 2026 and declared again on 25 February 2026 — a 3.70% yield at $140.38. This is the residue of a variable-dividend policy that paid $4.80 in a single quarter as recently as March 2023 and $15.00 as a Whiting-close special in July 2022: the dividend is ~73% below its peak. Management confirmed in May 2026 that it “currently do[es] not envision resuming variable dividends.” Distributions are supplemented by opportunistic repurchases, with excess free cash flow now directed to the balance sheet.

How profitable is the business?

Answered above. In summary: FY2025 GAAP net income $44.5M on $3,897M of oil, NGL and gas revenue; ROIC 1.6% (6.1% ex-goodwill); ROE 2.0%; field cash margin 59.8% of realized revenue, the lowest in the peer set examined; full-cycle margin $6.74/Boe in FY2025 against $36.93 in FY2022.

Is net income diverging from cash from operations?

Dramatically, and in the informative direction. FY2025 operating cash flow of $2,040.7M against GAAP net income of $44.5M is a 46x ratio. The reconciling items are DD&A of $1,470.2M (14.56/Boe, up 144% since FY2021), the $539.3M goodwill impairment, and derivative marks. Interpretation: this is not an earnings-quality red flag in the usual sense — the cash is real and working capital is clean. It is a capital-intensity signal. Net income is low because the depletion charge is high, and the depletion charge is high because the reserves being consumed cost a great deal to acquire. In FY2021 the field cash margin covered DD&A 6.3x; in FY2025 it covered it 1.6x. That convergence, not the divergence between net income and cash flow, is the number to watch.

Risks and Downside

What factors would cause the stock to decline?

In order of probability-weighted impact: (1) crude below ~$65 — free cash flow compresses toward ~$700M against a ~$1.4bn maintenance budget and a $293M base dividend, with only ~13% of 2027 oil hedged; (2) unwind of the geopolitical premium — the precedent is live and recent, the June 2026 ceasefire having removed 25% of the equity value in six weeks; (3) lifting cost failing to improve, invalidating both the corporate cost-of-supply claim and the inventory reclassification that underpins the ~10-year runway; (4) 4-mile disappointment at a larger sample than the current 12 producing wells; (5) another large, partly equity-funded acquisition at a ~1.0x recycle ratio; and (6) further negative reserve revisions, which have occurred in each of the last three years.

Risk of a catastrophic loss?

Low, and this is the genuinely reassuring part of the file. Net debt/EBITDA of 0.58x, zero drawn on a $2.75bn borrowing base reaffirmed at two consecutive redeterminations, ~$2.16bn of liquidity, and no maturity before October 2030. Stress-tested at $60 WTI the company still generates ~$385M of positive free cash flow; at $50 WTI, 2026 is roughly cash-neutral once the hedge floors are counted, and 2027 would require a capital cut rather than a financing. There is no borrowing-base-redetermination reflexivity and no refinancing wall to amplify a downturn. The equity can fall a great deal; the enterprise is not fragile.

Chance of a total loss?

Very low over any reasonable horizon, absent a sustained sub-$40 oil regime combined with a large debt-funded acquisition. The relevant historical caution is that this registrant has already produced a total loss once: Oasis Petroleum’s equity was wiped out in the 2020 Chapter 11, with $4,825.5M of asset impairments and stockholders’ equity of −$897.2M immediately before emergence. That outcome required a demand shock of unprecedented scale on a balance sheet carrying far more leverage than Chord carries today — 0.58x versus a pre-bankruptcy structure that could not survive. The lesson is not that it will happen again; it is that the asset base is high-cost enough that the capital structure is the only thing standing between a price shock and permanent impairment, and management has so far protected that capital structure well.

Recent News and Events

Has the business environment changed recently?

Twice, violently, in six months, and both times because of Iran rather than anything Chord did. US and Israeli strikes from 28 February 2026 drove WTI above $100 for the first time since July 2022; Chord ran from ~$104 to ~$146 in five weeks. The mid-June ceasefire unwound the premium (WTI ~$90.73 on 1 June to ~$70.02 on 29 June) and took the shares down 25% in six weeks. Iran’s 20 July repudiation of the memorandum of understanding, following a 18 July strike on a Kuwaiti oil facility, restored WTI to ~$84–85 and the shares retraced 24% in three weeks on below-average volume. The entire 2026 share-price record is this sequence. Management’s own planning assumption moved from $64 (February) to $80 (May) with no change to the capital programme.

Significant acquisitions?

The XTO Williston package: agreed 15 September 2025 at $550.0M, closed 31 October 2025 at $542.2M (a $55.0M deposit plus $487.2M at closing), effective 1 September 2025, funded with proceeds from the $750M 6.000% senior notes due 2030 and cash. Approximately 9,000 Boe/d including ~6,000 Bo/d. Management called it “Chord’s fifth Williston Basin deal in 5 years” and expects the re-permitting and re-spacing benefit to appear “more likely going into 2028.”

Change in accounting policies?

No policy change. But two accounting events are material to reading the numbers: the $539.3M goodwill impairment in Q2-2025 (100% of the Enerplus goodwill, non-deductible, driving an 81.7% FY2025 effective tax rate), and the self-identified prior-period tax provision error corrected in Q1-2026 as a $41.8M benefit without restatement.

Recent changes — new markets, facilities, management?

No new markets and no change in senior leadership; Daniel Brown remains President and CEO, with Richard Robuck as CFO, Darrin Henke as COO, Michael Lou as Chief Strategy and Commercial Officer and Shannon Kinney as Chief Administrative Officer and General Counsel. The operational changes are internal and worth noting: the production-engineering organisation has been bifurcated between ESP (high-rate) and rod-pump well populations; artificial-lift optimisation now uses machine-learning tooling across ~5,000 operated wells; simulfrac operations have increased pumping hours per day by 20% and save ~$300,000 per well versus zipper operations; and the drilling programme has shifted decisively toward longer laterals — ~40% of 2026 turn-in-lines and ~60% of spuds are four-mile, with ~80% of turn-in-lines being three- or four-mile.

The single most important forward-looking item is that Chord reports second-quarter 2026 results on 5 August 2026 — four days after this report date. Every forward figure here rests on Q1-2026 disclosure and the 6 May 2026 guidance update. A news sweep through 1 August 2026 surfaced nothing material beyond the earnings-date notice, routine 13F filings and sell-side previews.

APPENDIX B — Source Appendix

Chord Energy Corporation (NASDAQ: CHRD) · 1 August 2026

Every non-obvious claim in the analysis above and in Appendix A traces to a source below. Primary sources are listed first. Access dates are given where the source is a live feed rather than a filed document.

1. SEC filings — primary (CIK 0001486159)

The trailing 60-month corpus was enumerated from the SEC EDGAR filing index for the registrant, back to 26 July 2021. It comprises 404 filings: 181 Form 4, 59 8-K, 30 SC 13D/G, 28 Form 144, 17 Form 3, 16 Form 425, 15 10-Q, 13 DEFA14A, 12 SCHEDULE 13G/A, 5 DEF 14A, 5 10-K, 4 S-8, 4 8-K/A, 2 SD, 2 S-3ASR, 1 S-4, 1 S-4/A, 1 PREM14A and 1 DEFM14A. Documents relied upon:

Method note on Form 4 plan flags: the 10b5-1 designation was read from the checkbox state, not from the presence of the printed “10b5-1” label, which appears on every Form 4 regardless of whether the box is checked.

2. SEC XBRL structured data

SEC EDGAR XBRL company-facts API, CIK 0001486159, accessed 26 July 2026. Series relied upon: us-gaap:NetIncomeLoss (2009–2025 and quarterly 2025–2026), us-gaap:Goodwill, us-gaap:GoodwillImpairmentLoss, us-gaap:StockholdersEquity (including the 18/19 November 2020 fresh-start reset from −$897,167,000 to +$965,615,000), us-gaap:OilAndGasPropertySuccessfulEffortMethodGross (the $9,463.0M → $810.6M write-down at emergence), us-gaap:AssetImpairmentCharges (the $4,825,530,000 predecessor charge for 1 January – 19 November 2020), us-gaap:ImpairmentOfOilAndGasProperties, and the CostsIncurred* family.

3. Company communications

Earnings-call transcripts, read in full:

• Q2-2025, call 7 August 2025 — the 4-mile economics claim (“90% to 100% more EUR for only 40% to 60% more CapEx… an $8 to $12 per barrel cost of supply reduction”); the Rystedt well; LOE $10.02/Boe; NGL at 9% of WTI and gas at 32% of Henry Hub; net debt ~$810M at 31 July; simulfrac savings.
• Q3-2025, call 5 November 2025 — the XTO close and its ~9,000 Boe/d; the 80% fourth-mile underwriting assumption; 2026 preliminary guidance (157–161 MBopd, ~$1.4bn capital, “approximately 4% higher oil volumes for roughly $100 million less in capital”); the midstream contract repricing worth “$30 million to $50 million a year”; the stated capital-return waterfall.
• Q4-2025, call 26 February 2026 — “a low to no oil growth program”; five rigs split between three- and four-mile wells; the “$6.7 billion of capital returned since 2021” statement; the 80%-long-lateral inventory conversion goal achieved; the $160M of controllable-cost improvement; Dingmann’s “Bakken generally having a bit more fixed cost” exchange; the inventory-reclassification description.
• Q1-2026, call 6 May 2026 — the Tuni pad (first full four-mile DSU); 12 four-mile laterals producing and 33 drilled; the telegraphed fourth-mile re-underwriting; the sub-$60 WTI inventory-screen definition; the shelving of variable dividends and redirection of excess FCF to the balance sheet; “our stock is not underwriting anywhere near that level”; ~one-third of 2026 and under 15% of 2027 oil hedged; the unanswered Jefferies question on acquisition leverage capacity.

4. Market and quantitative data feeds

5. Third-party and media sources

All secondary sources below were used for macro context or sentiment triage only; no memo conclusion rests on any of them without a primary cross-check.

• Reuters, “Chord Energy to buy assets in Williston Basin for $550 million,” 15 September 2025 — cross-checked against the FY2025 10-K, which discloses $550.0M agreed and $542.2M paid.
• CNBC, “Brent oil heads for record monthly surge, WTI settles above $100 for first time since 2022,” 30 March 2026; “A timeline of how the Iran war shook oil prices,” 21 April 2026; “Oil prices fall as more tankers exit Strait of Hormuz,” 26 June 2026.
• EIA, Today in Energy, “Crude oil and petroleum product prices increased sharply in the first quarter of 2026.”
• OPEC Monthly Oil Market Report summary via IndexBox, June 2026 — WTI $90.73 (1 June) to $70.02 (29 June).
• FXLeaders (14 July 2026) and FXDailyReport (20–21 July 2026) — the July re-rally following Iran’s 20 July repudiation of the memorandum of understanding and the 18 July strike on a Kuwaiti oil facility. Labelled as secondary financial media; the price moves are taken from the AZI CSV, only the attribution is from these sources.
• Zacks — Q3-2025 EPS $2.35 versus $2.24 estimate (4 November 2025); Q1-2026 adjusted EPS $4.56 versus $3.35 (5 May 2026); Rank #1 upgrade (16 April 2026).
• MarketBeat aggregation via defenseworld.net — sell-side consensus “Moderate Buy,” 9 buy / 4 hold of 13 firms (13 January 2026); short interest of 4,394,786 shares at the 13 March 2026 settlement, +20.9% month over month, ~7.8% of shares outstanding (report dated 2 April 2026). Explicitly labelled in the memo as stale and secondary-sourced.
• GuruFocus, 8 July 2026 — referenced only as evidence of the prevailing bullish tape.

6. Peer benchmarking and analytical frameworks

• Peer benchmarking draws on the FY2025 Form 10-K and quarterly disclosures of APA Corporation, Diamondback Energy, EOG Resources, ConocoPhillips, Devon Energy, Permian Resources, Ovintiv and SM Energy — the source for the comparative lease-operating-expense per Boe, field cash margin, recycle-ratio and EV/EBITDA figures. The multiples were struck on dates spread across June and July 2026, a window over which crude moved materially; peer multiples are therefore used ordinally, not cardinally, and this is stated in the body.
• Analytical frameworks: Bruce Greenwald and Judd Kahn, Competition Demystified (barriers to entry; the three genuine advantage types — supply/cost, demand/captivity, and economies of scale with captivity; the market-share-stability and ROIC tests; earnings-power value versus asset value); and Edward Chancellor, ed., Capital Returns: Investing Through the Capital Cycle (Marathon Asset Management) on supply-side capital-cycle analysis and the asset-growth anomaly. Applied in Sections 3, 4, 7 and 10.

Position disclosure. The author holds no position, long or short, in Chord Energy Corporation or in any peer security mentioned, and has no business relationship with any company discussed. This analysis is position-agnostic throughout.

7. Data reliability notes

1. ROIC.ai capital-structure ratios were rejected for this issuer. tot_debt_to_tot_cap of 44.3% for FY2025 implies total capital of ~$3,670M, irreconcilable with EDGAR stockholders’ equity of $8,080.0M plus $1,479.6M of debt. Its short_and_long_term_debt of $1,626.1M also includes lease liabilities; actual borrowings are $1,479.6M carrying and $1,500.0M face. All leverage figures in this report are computed from the filings.
2. ROIC.ai TTM EBITDA is GAAP-derived and includes the goodwill impairment; the memo reconciles it explicitly to the adjusted figure rather than switching bases silently.
3. The ROIC.ai transcript listing endpoint returns a cross-ticker list rather than filtering to the requested issuer, and its transcript retrieval requires an exchange-qualified symbol. Transcripts were therefore fetched by explicit year and quarter.
4. FactorsToday loadings must be read within a single model, never across models — the orthogonalisation basis is hierarchical and level-dependent, so the same factor’s beta legitimately differs between the Base, +Sector, +Industry and All-Factors specifications. All comparisons in this report are within-model.
5. FactorsToday leaderboard returns are annualised at every horizon, including the short ones. The m6 return of +118.07% de-annualises to +47.7%, matching the AZI CSV’s +47.6% total return; the m6 Sharpe of 2.76 is a correct annualised reading of one strong half-year, not a durable characteristic.
6. No y10 or lifetime risk-adjusted record exists for this entity. FactorsToday has only ~1,422 trading days of history because the registrant relisted after Chapter 11 on 20 November 2020. The pre-bankruptcy Oasis record is a different capital structure and has not been spliced on.
7. Short interest is a 13 March 2026 settlement figure from an aggregator and is labelled stale and secondary wherever it appears.
8. Q2-2026 results are scheduled for release on 5 August 2026, four days after this report date. All forward figures rest on Q1-2026 disclosure and the 6 May 2026 guidance update.