Devon Energy sells oil, natural gas and natural gas liquids, and the third quarter ended September 30, 2026 was its first full quarter owning Coterra. The enlarged business generated $8.14 billion of operating cash in the first nine months of 2026, yet cash including restricted funds ended September at $413 million. Drilling, acreage purchases, debt repayments and shareholder distributions together used more cash than operations supplied. Devon now needs to turn its larger collection of wells, undeveloped land and transport rights into better results from each dollar it spends.
Research cutoff: November 11, 2026, New York time. The latest substantive company materials used are the November 5 earnings materials and November 6 filing and earnings call.
Source: Devon’s third-quarter 2026 Form 10-Q, consolidated cash-flow statement, p. 9; Note 2, pp. 12–14.
1. The merger explains most of Devon’s larger business
Devon improved on a combined-company basis, while most reported growth came from adding Coterra. Coterra joined Devon on May 7. Consequently, the 2026 accounts include its operations only after that date, while the 2025 reported comparisons exclude Coterra entirely.
The merger brought additional Permian and Anadarko properties and a large Pennsylvania natural-gas business in the Marcellus. These assets substantially changed both Devon’s size and the products it sells. In the first nine months, production averaged 1.290 million barrels of oil equivalent a day, against 836,000 a year earlier. Acquired Coterra properties accounted for 431,000 of the 454,000 daily increase—about 95%. That is a measure of the merger’s contribution, not a measure of drilling success on Devon’s original acreage.
The reported earnings show the scale of the change:
| Consolidated results; USD millions except per-share amounts | Third quarter 2025 | Third quarter 2026 | First nine months 2025 | First nine months 2026 |
|---|---|---|---|---|
| Oil, gas and natural gas liquids sales | 2,809 | 5,939 | 8,645 | 14,022 |
| Total reported revenue | 4,331 | 6,860 | 13,067 | 18,084 |
| Earnings before income tax | 912 | 1,252 | 2,719 | 3,802 |
| Net earnings attributable to Devon | 687 | 1,008 | 2,080 | 3,039 |
| Diluted earnings per share, USD | 1.09 | 0.88 | 3.27 | 3.36 |
Source: Third-quarter 2026 Form 10-Q, consolidated earnings statement, p. 7; Note 8, p. 20; production discussion, pp. 36–37. Total revenue includes commodity hedging gains or losses and marketing and midstream revenue, in addition to sales of Devon’s production.
The filing also estimates what both years would have looked like if the merger had occurred on January 1, 2025. On that basis, third-quarter revenue rose 11.9%, and consolidated net earnings rose 9.9%, from $917 million to $1.008 billion. Those are much smaller increases than the reported 58.4% revenue growth and 46.7% growth in earnings attributable to Devon. The comparable first-nine-month estimates also improved: revenue rose 10.9% and net earnings 13.6%.
These combined-company figures, called pro forma results, adjust historical financial information for the transaction. They are useful for controlling for the change in company size, but they are not a forecast or a calculation of merger savings.
The share count explains why quarterly profit and earnings per share moved in opposite directions. Devon issued approximately 531.6 million shares to Coterra shareholders. Average diluted shares rose 82.2% from a year earlier, far more than quarterly profit grew. Dividing that profit among more shares lowered reported diluted earnings per share to $0.88. On the filing’s combined-company comparison, diluted earnings per share instead rose from $0.79 to $0.88.
Sources: Third-quarter 2026 Form 10-Q, Note 2, pp. 13–14, and Note 8, p. 20. Percentage changes are calculated from the disclosed figures; the underlying combined-company inputs are reproduced in the calculation notes.
Devon reports one combined U.S. reporting segment. Basin production and costs help explain performance, but the filing does not disclose separate operating profits for each basin.
2. Higher oil prices helped, while hedges and merger costs absorbed part of the gain
Devon’s larger production base benefited from stronger oil prices, but it did not keep every dollar of that benefit. Oil supplied 72.5% of third-quarter sales from Devon’s own production. Gas made up much more of its production volume after the merger, yet oil remained the main source of product revenue.
A barrel of oil equivalent, or Boe, combines oil, gas and natural gas liquids according to energy content. It does not mean those products sell for the same amount. Devon says the change in its asset and product mix helped lower operating cost per Boe. That decline therefore cannot be read entirely as savings on its original wells.
The first-nine-month prices make the different product trends clear:
| Average selling price before hedges | First nine months 2025 | First nine months 2026 |
|---|---|---|
| Oil, USD per barrel | 64.66 | 84.34 |
| Natural gas, USD per thousand cubic feet | 1.78 | 1.34 |
| Natural gas liquids, USD per barrel | 18.79 | 22.01 |
| All products, USD per Boe | 37.86 | 39.83 |
Source: Third-quarter 2026 Form 10-Q, Note 1, p. 11; production and realized-price tables, pp. 36–37. Oil’s revenue share is calculated as $4,307 million divided by $5,939 million.
Devon paid counterparties under contracts that had limited part of its exposure to commodity prices. Such hedges can support receipts when prices fall, but they also surrender some benefit when prices rise. For the first nine months, net hedge settlements were a $358 million cash payment, compared with a $107 million receipt a year earlier.
Hedges also affected profit before the related cash payments occurred. In the third quarter, the $914 million derivative loss comprised $185 million of cash settlements and $729 million of changes in the estimated value of contracts. The valuation loss reduced reported earnings immediately. It was not an additional $729 million paid during the quarter.
This helps explain why net earnings fell from about $1.9 billion in the second quarter to $1.0 billion in the third, even though Devon owned Coterra for more days. Hedge valuation changes swung from a $530 million gain in the second quarter to the $729 million loss in the third—a $1.259 billion adverse movement before tax. The second quarter also contained the Fervo investment gain discussed below. Treating the entire quarterly profit decline as weaker well performance would therefore miss the largest accounting movements.
Source: Third-quarter 2026 Form 10-Q, cash-flow statement, p. 9; hedge settlements and other earnings items, pp. 34–35 and 38–39.
The costs of producing and handling a larger volume also increased. First-nine-month production expenses rose from $2.706 billion to $3.938 billion. The cost of operating wells fell from $6.32 to $5.33 per Boe, while gathering, processing and transport rose from $2.78 to $3.05. Devon attributes those unit-cost changes partly to the new asset and product mix, alongside benefits from its earlier business-improvement program.
Depreciation and depletion—the accounting charges that spread property costs over their use and production—rose from $2.705 billion to $4.004 billion as the acquired properties and new wells entered the accounts.
Marketing and midstream activity also generated substantial revenue with little direct profit. Third-quarter revenue of $1.835 billion was less than its $1.855 billion of related expenses, leaving a $20 million loss before other company costs. That revenue contributes to company size without contributing the same proportion of earnings.
Profit therefore did not rise as quickly as reported quarterly revenue. The third-quarter pretax margin fell from 21.1% to 18.3%. Consolidated net margin fell from 16.0% to 14.7%. For the first nine months, however, consolidated net margin improved from 16.2% to 16.8%. The different results show why the quarter and the cumulative period should be assessed separately.
Source: Third-quarter 2026 Form 10-Q, earnings statement, p. 7; expenses, pp. 38–39. Margins use reported total revenue and consolidated profit, including noncontrolling interests in the 2025 comparator.
Merger savings remain an important opportunity rather than a fully demonstrated annual result. In November, Devon raised its expected annual pace of savings at the end of 2026 from $200 million to $350 million. It expects roughly $700 million of benefits during 2027 and at least a $1 billion annual pace by that year’s end. These pretax targets include more efficient capital spending, better operating margins and lower corporate costs; they are not all reductions in the earnings statement’s administrative expense line. The annual pace at year-end also differs from savings actually captured during that year.
Source: Devon’s November 5, 2026 earnings release, “Accelerating Synergies”; third-quarter Form 10-Q, pp. 30–31.
Getting there has a cost. Devon recorded $334 million of restructuring and transaction expenses in the first nine months, including $48 million of noncash share awards that vested early. Employee-related restructuring liabilities still totaled $131 million at September 30, and further merger-related payments are expected mainly through the end of 2027.
Other unusual items pull the comparison in both directions. This year included a $201 million pretax gain when Fervo’s public offering increased the accounting value of Devon’s investment. Last year included a $307 million pretax gain on selling Matterhorn and a $254 million headquarters-property impairment.
In addition, 2026 net profit benefited from a $50 million tax release in the third quarter and a $56 million deferred-tax benefit in the second. None of those gains establishes higher recurring profit from selling oil and gas. The calculation notes separate these items and their tax treatment.
Source: Third-quarter 2026 Form 10-Q, Notes 2 and 5–7, pp. 14 and 18–19; Note 13, p. 21; merger-payment discussion, p. 44.
3. Operating cash covered drilling, but not every use of cash
Devon generated a substantial surplus after capital spending, then used it for acquisitions, distributions and debt repayment. Operating cash rose 57.2% in the first nine months. That growth funded the expanded drilling program, but land purchases created a much larger additional claim on cash than a year earlier.
The following calculation uses actual cash payments. Here, free cash flow means operating cash less the capital-expenditure line in the cash-flow statement. It excludes property acquisitions, which are shown separately.
More cash remained after capital spending
| Cash generated and selected uses; USD millions | First nine months 2025 | First nine months 2026 |
|---|---|---|
| Operating cash generated | 5,177 | 8,137 |
| Capital expenditures paid | 2,760 | 3,621 |
| Free cash flow on this cash-payment basis | 2,417 | 4,516 |
| Property and equipment acquisitions paid | 221 | 3,239 |
| Cash remaining after both kinds of investment | 2,196 | 1,277 |
| Dividends and share repurchases paid | 1,270 | 1,567 |
| Debt principal repaid | 485 | 1,250 |
| Surplus or shortfall after the listed uses | 441 | −1,540 |
Source: Third-quarter 2026 Form 10-Q, cash-flow statement, p. 9. Outlays are positive in the spending rows and are subtracted. This table isolates the main allocations; the complete cash reconciliation, including cash acquired with Coterra and other flows, appears in the calculation notes.
This was an active use of financial resources. Devon acquired about 16,300 net undeveloped Permian acres through a federal lease sale for approximately $2.6 billion, using cash on hand. The purchase gives it more places to drill in the future. It also means cash was spent well before those new wells could contribute production.
The merger itself was paid for with shares, not a $24.9 billion cash withdrawal. It brought $581 million of cash onto Devon’s balance sheet. Even with that addition, total cash including restricted funds fell $1.021 billion from year-end 2025. In the third quarter alone, it fell $596 million.
Source: Third-quarter 2026 Form 10-Q, cash-flow statement, p. 9, and Note 2, pp. 12–14.
Profit and cash also differed because the accounts recognize some costs without a current cash payment and some sales before customers pay. First-nine-month net earnings of $3.039 billion included $4.004 billion of depreciation and depletion and $843 million of net noncash hedge losses. Those two items explain much of the gap between profit and operating cash.
Amounts still owed by customers and operating partners used $649 million of cash during the nine months. Conversely, increased amounts owed to suppliers and production-interest owners supplied $562 million. These figures measure payment timing in the cash-flow statement; they should not be inferred from balance-sheet changes that also include the acquisition. Coterra alone brought $1.102 billion of receivables into Devon’s accounts.
The third quarter was less favorable for collections and payments: changes in operating assets and liabilities used $657 million, including $384 million from higher receivables. That reduced cash available for other purposes even as the company recorded the related sales. It does not, by itself, show that customers were failing to pay.
Source: Third-quarter 2026 Form 10-Q, cash-flow statement, p. 9; acquisition balances, p. 13; Note 10, pp. 20–21.
Tax timing also helped the year-to-date cash position. Devon recorded a $218 million reduction in current tax expense following new guidance, with an equal increase in deferred tax expense. That postponed tax rather than increasing net profit. It should not be added a second time to the operating cash already reported.
Third-quarter cash flow after actual capital payments was $1.344 billion. Devon’s adjusted measure was $2.010 billion: it removes payment-timing movements and selected merger costs, and uses spending incurred instead of cash paid. The calculation notes reconcile both measures.
Sources: Third-quarter 2026 Form 10-Q, Note 7, p. 19, and cash-flow statement, p. 9; third-quarter supplemental tables, p. 12.
4. The Eagle Ford sale exchanges current output for cash and a more concentrated drilling plan
The planned sale would replenish cash while giving up production that contributes cash today. Management’s stated purpose is to concentrate on properties offering a longer development life and better returns on future spending. The decision should therefore be judged by what the remaining properties can produce, as well as by the money received at closing.
On October 8, Devon agreed to sell approximately 90,000 net Eagle Ford acres to Crescent Energy for about $4.2 billion in cash, subject to adjustments. By the November reporting date, Devon expected closing in early 2027. The assets represented about 3% of post-merger proved reserves. They produced 61,000 Boe a day in the third quarter, about 3.7% of Devon’s total. Their quarterly production had declined because existing wells produced less over time and new-well completions were unevenly timed.
The sale had not closed at September 30, and the properties were not yet classified as held for sale. They remain in the reported assets and operating results. Devon expects a material accounting gain when the transaction closes, but neither that gain nor sale proceeds belong in the third-quarter cash balance.
Source: Third-quarter 2026 Form 10-Q, Note 2, p. 14; portfolio strategy and production, pp. 30 and 32–33.
Eagle Ford’s third-quarter field cash margin was $45.66 per Boe, versus $34.95 in the Permian. This is selling prices less field operating costs, transport and production-related taxes. It excludes drilling, depreciation, corporate costs and hedges. Devon is surrendering meaningful current cash contribution to concentrate future investment elsewhere.
Source: Third-quarter supplemental tables, p. 9.
Crescent’s own announcement also describes useful drilling locations beside its existing operations and identifies approximately $140 million of prospective annual savings from drilling, operations and marketing. Those are the buyer’s estimates, not Devon earnings. They nevertheless show why the properties can fit a competitor’s development plan even as Devon chooses to direct more spending elsewhere.
Source: Crescent’s October 8, 2026 acquisition announcement, pp. 1–2.
Devon estimates roughly $3.5 billion of proceeds after tax and effective-date adjustments, to support debt reduction and faster buybacks. The gross sale price is therefore not the cash expected to remain available. Management plans more than $1 billion of fourth-quarter repurchases and approximately $1.5 billion of additional debt retirement in 2027. Buybacks distribute cash and reduce shares outstanding; accelerating them also leaves less cash available for investment or unexpected obligations.
Sources: Devon’s November 5 earnings release, “Return of Capital” and “Eagle Ford Divestiture”; November 5 shareholder letter, p. 2.
The next development plan is increasingly centered on the Permian. It already supplied 54% of third-quarter production and 70% of oil production. Management expects to direct roughly 75% of 2027 capital spending there. The newly acquired federal acreage is a later contribution: management expects to start drilling around mid-2027 and obtain meaningful production in early 2028.
Devon’s initial 2027 plan calls for approximately $5.3 billion of capital spending, about 525,000 barrels a day of oil and 1.6 million Boe a day in total. These production plans assume the Eagle Ford sale and should not be compared directly with the larger third-quarter portfolio. The spending plan also excludes potential land acquisitions and approximately $400 million expected for Solitude in 2027. Those exclusions matter when assessing the company’s total cash needs.
Sources: Third-quarter 2026 Form 10-Q, pp. 32–33; November 6 earnings-call transcript, pp. 4–5, prepared remarks. The 2027 amounts are preliminary management plans, not realized results.
The immediate operating outlook is steadier. Fourth-quarter guidance calls for 1.66–1.70 million Boe a day and $1.290–$1.395 billion of capital spending, with Eagle Ford still included. The larger test comes later: whether merger savings and the new acreage let Devon sustain and gradually expand production with less spending on comparable properties.
Source: Devon’s fourth-quarter 2026 guidance, p. 1.
5. Getting gas to better markets is as important as producing more of it
More gas production helps only when Devon can transport and sell it on workable terms. In the first nine months, the Henry Hub gas benchmark rose, but Devon’s average selling price before hedges fell. Its exposure to local markets, including weak Permian pricing, mattered more than the direction of the national benchmark alone.
The third quarter improved. Devon’s unhedged gas price rose to $1.97 per thousand cubic feet from $0.35 in the second quarter. A full quarter of Marcellus production shifted the mix away from the Permian, where negative Waha prices had hurt the earlier period. Marcellus supplied 46% of third-quarter gas volumes. That diversification changed Devon’s receipts even though Henry Hub moved only modestly between the two quarters.
Source: Third-quarter 2026 Form 10-Q, pp. 32–33 and 37.
This transport problem has a history. In September 2024, the U.S. Energy Information Administration explained that rising gas production alongside oil had outgrown regional pipeline capacity. Producers could have gas to sell but too little room to send it to distant buyers, pushing local prices below zero. The 2026 experience shows why Devon cannot rely on more drilling alone to improve gas earnings.
Source: EIA, “Natural gas pipeline capacity from the Permian Basin is set to increase,” September 10, 2024. This source supplies historical context, not a November 2026 price assessment.
Devon is responding with transport rights and ownership interests. It contributed $83 million for a 25% interest in Solitude during the third quarter and secured firm transport capacity. The project will build two pipelines connecting Permian production to Katy, near Gulf Coast demand. The first phase is planned for the second half of 2029 and the second for 2030, subject to approvals. It cannot explain an improvement in present-quarter gas prices.
Devon expects to invest about $500 million in Solitude overall. The filing separately discloses approximately $900 million of maximum exposure under the venture agreement, including its investment and future unfunded commitments. The expected investment and maximum contractual exposure are different measures; the latter is neither an expected loss nor an amount to add on top of the former.
Sources: Third-quarter 2026 Form 10-Q, Note 13, pp. 21–22; Devon’s August 17, 2026 Solitude announcement, project timing and ownership.
The project’s partners include another Permian producer, Diamondback, alongside infrastructure companies. That shared infrastructure can help Devon reach better markets, but it also helps competitors move their gas. The likely benefit is more dependable access and less exposure to local transport shortages; the amount earned still depends on destination prices, pipeline charges and timely completion. Devon’s advantage must come from its acreage, costs and commercial arrangements as well as access to the pipe.
Source: Devon’s Solitude announcement, August 17, 2026, ownership and transport discussion. The business implications are an assessment of the disclosed arrangements.
6. Borrowing capacity provides flexibility, but unrestricted cash is small
Devon has substantial borrowing room and no debt maturity until May 2027, while its cash on hand leaves limited room for competing uses. Of the $413 million reported cash balance, $61 million was restricted. Unrestricted cash and cash equivalents were $352 million.
The undrawn revolving credit facility provides approximately $3 billion of additional capacity and matures in March 2031. The commercial-paper program uses that same support; it is not another independent $3 billion reserve. Devon’s covenant debt-to-capitalization ratio was 17.1%, against a maximum of 65%. The lender’s definition adjusts capitalization, including adding back certain noncash write-downs, so it differs from a simple balance-sheet debt ratio.
Source: Third-quarter 2026 Form 10-Q, cash-flow statement, p. 9; Note 14, pp. 22–24.
The balance sheet grew mainly because Devon acquired another company’s properties and obligations:
| Consolidated financial position; USD millions | December 31, 2025 | September 30, 2026 |
|---|---|---|
| Cash, including restricted cash | 1,434 | 413 |
| Accounts receivable, net | 1,792 | 3,539 |
| Inventory | 336 | 382 |
| Property and equipment, net | 25,419 | 63,182 |
| Goodwill | 753 | 753 |
| Investments | 727 | 1,074 |
| Total assets | 31,599 | 70,814 |
| Financing debt, carrying amount | 8,389 | 10,636 |
| All other liabilities | 7,682 | 18,165 |
| Stockholders’ equity | 15,528 | 42,013 |
Source: Third-quarter 2026 Form 10-Q, balance sheet, p. 8. “All other liabilities” is calculated as total liabilities less short- and long-term financing debt; it includes operating obligations, leases and deferred taxes. Selected asset rows do not add to total assets because smaller categories are omitted.
Coterra brought $34.913 billion of property and equipment into the acquisition accounting. Devon’s total property balance increased $37.763 billion, so the acquisition explains most of that change. The allocation remains preliminary. In particular, $14.002 billion was assigned to acquired unproved properties and properties under development. These amounts depend on estimates of future drilling, costs and commodity prices; their presence on the balance sheet does not mean they are already producing cash.
Goodwill stayed at $753 million: the preliminary merger allocation did not create a new goodwill balance. Inventory increased only $46 million, of which $31 million entered with Coterra, making inventory a small part of the expansion. Investments rose partly because of the Fervo accounting gain and the Solitude contribution, rather than an equivalent increase in cash received.
Source: Third-quarter 2026 Form 10-Q, Notes 2 and 12–13, pp. 13 and 21–22; purchase-accounting estimates, p. 46.
The liability increase also needs to be separated by purpose. Devon assumed $3.5 billion of Coterra debt and then repaid $1.25 billion of principal during the nine months. Deferred income-tax liabilities rose $6.988 billion, with $6.690 billion arriving in the acquisition allocation. These tax balances are not bonds due for immediate repayment.
Suppliers and production-interest owners were owed $4.012 billion at September 30, up from $2.281 billion. These are operating payments, distinct from bank and bond financing. Other current liabilities also include $801 million of derivative liabilities, up from $1 million. The change reflects the estimated future settlement burden of hedges, rather than new borrowing. Overall, current liabilities exceeded current assets by $2.025 billion, reinforcing the importance of collections, ongoing operating cash and the credit facility.
Source: Third-quarter 2026 Form 10-Q, balance sheet, p. 8; acquisition allocation, p. 13; Note 3, p. 17; Note 14, pp. 22–24.
The next debt payments are spread across several years:
| Contractual principal due; USD millions | Amount |
|---|---|
| 2027 | 1,213 |
| 2028 | 325 |
| 2029 | 500 |
| 2030 | 585 |
| 2031 and later | 8,041 |
| Total principal | 10,664 |
Source: Third-quarter 2026 Form 10-Q, Note 14, p. 22. Principal differs from the $10,636 million carrying amount because of premiums and issuance costs. The 2027 total includes $750 million in May, $73 million in September and $390 million in October.
The stated coupons imply approximately $583 million of annual interest on the September 30 principal, before future repayments or refinancing. Third-quarter interest expense on debt was $150 million, versus $125 million a year earlier. Debt is fixed-rate, which limits immediate exposure to changes in borrowing rates, although refinancing later may carry a different cost. Total recognized lease liabilities were another $565 million, up from $299 million at year-end. Of the September balance, $161 million was current. Some contracted equipment leases had not started and were excluded.
Source: Third-quarter 2026 Form 10-Q, Notes 14–15, pp. 22–24; market-risk discussion, p. 47. Annual coupon cost is calculated from each disclosed principal and coupon, not a forecast of cash interest paid in a particular year.
Equity rose chiefly because shares paid for Coterra, not because Devon retained $26 billion of earnings. The merger added $24.946 billion to equity; profit added $3.039 billion, while dividends and share purchases reduced it. Most repurchased shares were retired. Consequently, the $7 million treasury-stock balance does not measure the year’s total repurchases. Employee stock grants also added shares, partly offsetting the reduction from retirements.
Source: Third-quarter 2026 Form 10-Q, equity statement, p. 10; Notes 4 and 17, pp. 17–18 and 25.
7. Future obligations make cash flexibility valuable
Future cash needs extend beyond debt and drilling. The discounted asset-retirement liability for closing wells and restoring sites reached $1.241 billion, up from $906 million at year-end. The increase included $177 million assumed with Coterra and $107 million of estimate revisions, primarily reflecting changed cost estimates.
Separately, Devon had accrued about $120 million for legacy decommissioning contingencies. For East Bay federal properties, the original estimate was $125 million, with approximately $100 million expected from bonds and a security account. Reimbursements began in the third quarter, but additional obligations and recovery uncertainty remain.
Environmental cases add an unquantified exposure. Devon is negotiating a North Dakota emissions and permitting settlement that may require penalties and remedial work; it cannot estimate the potential loss. Royalty lawsuits, Louisiana coastal claims and a Delaware climate case also remain. Canadian tax disputes may require material cash deposits while contested assessments are resolved. Their eventual cash cost remains uncertain.
Source: Third-quarter 2026 Form 10-Q, Notes 16 and 18, pp. 24 and 26–27; tax contingencies, p. 45.
Commodity prices remain the broadest cash risk. Devon expected hedges to cover about 35% of 2027 oil production and 10% of gas production, excluding Eagle Ford. Some oil contracts are three-way collars: below a lower contractual threshold, protection weakens and receipts again fall with prices. Together with fixed transport commitments and continuing drilling needs, this makes the timing of buybacks, acquisitions and debt reduction a meaningful management choice.
Sources: Third-quarter 2026 Form 10-Q, Note 3, pp. 15–16, and p. 33; 2025 Form 10-K, Note 1, derivative policy, pp. 59–60, and Note 18, contractual operating agreements, p. 86.
8. The next test is more cash from each dollar invested
Devon has a stronger operating cash base, but its expansion has committed much of the immediate financial benefit. The merger adds useful assets and geographic choice, and the combined-company earnings comparison is positive. The acreage purchase and pipeline investment also address identifiable business needs: future drilling locations and access to gas buyers.
The benefits arrive over several years, while spending and distributions need funding now. Until new projects contribute, Devon must rely on its existing wells, collections and financing flexibility. Completing Eagle Ford would ease that funding task while reducing the business that generates operating cash.
Devon has a credible plan to improve the enlarged business, supported by existing cash generation and specific investment projects. Its success depends on integration savings and productive new wells arriving before spending repeatedly consumes the remaining cash reserve. Stronger cash generation from comparable properties would confirm progress; delayed benefits or distributions that repeatedly outrun that cash would weaken the business’s flexibility.
Reporting basis and calculation notes
Reporting basis: Devon Energy Corporation and consolidated subsidiaries; SEC registrant DEVON ENERGY CORP/DE, CIK 0001090012, ticker DVN. Form 10-Q, accession 0001193125-26-451216, filed November 6, 2026, for the quarter ended September 30, 2026. The accounts are unaudited U.S. GAAP interim statements. Quarter comparisons use July–September; cumulative comparisons use January–September. Balance-sheet changes use December 31, 2025 and September 30, 2026. Devon is the accounting acquirer, and Coterra is included from May 7, 2026.
Sources: SEC filing, cover and Note 1; SEC submissions record; SEC company financial facts. Checks used this accession, the stated period dates and the appropriate dollar or dollar-per-share units. Customer-contract revenue excludes derivatives and therefore differs from total reported revenue. Consolidated net earnings differ from earnings attributable to Devon in 2025 because of noncontrolling interests.
Calculation notes: All monetary amounts below are USD millions unless specified. Percentage growth is the current amount divided by the comparable prior amount, less one. Rounding may produce small differences from percentages based on Devon’s unrounded records. A Boe uses six thousand cubic feet of gas as the energy equivalent of one barrel of oil; this is not a selling-price equivalence.
The comparable-company inputs verify how much of reported growth comes from changing the size of the company:
| Combined-company estimates; USD millions except per-share amounts | Third quarter 2025 | Third quarter 2026 | First nine months 2025 | First nine months 2026 |
|---|---|---|---|---|
| Revenue | 6,133 | 6,860 | 18,719 | 20,754 |
| Consolidated net earnings | 917 | 1,008 | 3,056 | 3,472 |
| Diluted earnings per share, USD | 0.79 | 0.88 | 2.61 | 3.02 |
Source: Third-quarter Form 10-Q, Note 2, p. 14. These estimates assume the merger occurred on January 1, 2025; they do not remove all unusual items.
Calculation notes: Devon presents pretax earnings rather than a separate operating-profit subtotal. This report uses reported pretax and net earnings, explaining production costs, financing costs and other earnings movements separately. Pretax margins divide $1,252 million by $6,860 million for the third quarter of 2026 and $912 million by $4,331 million for the third quarter of 2025.
Source: Third-quarter Form 10-Q, earnings statement, p. 7.
The following items explain why the reported earnings comparison includes more than changes in production profitability. Signs show the effect on earnings, not a proposed adjustment:
| Selected earnings items; USD millions | First nine months 2025 | First nine months 2026 | Measurement |
|---|---|---|---|
| Fervo investment gain | 0 | +201 | Pretax, noncash investment gain |
| Matterhorn sale gain | +307 | 0 | Pretax; 2025 after-tax gain was 239 |
| Headquarters-property impairment | −254 | 0 | Pretax asset write-down |
| Restructuring and transaction costs | −36 | −334 | Pretax costs |
| Release of tax uncertainties and related interest | — | +50 | Benefit included in income-tax expense |
| Release of state deferred-tax valuation allowances | — | +56 | Benefit included in income-tax expense |
Source: Third-quarter Form 10-Q, Notes 2 and 5–7, pp. 14 and 18–19; Note 13, p. 21. Dashes indicate no matching item separately identified in this comparison. Pretax items are not added directly to after-tax net income. The $218 million current-tax benefit had an equal deferred-tax expense and therefore no net earnings benefit.
The complete cash movements reconcile the cash balances, including restricted cash:
| Cash reconciliation; USD millions | First nine months 2025 | First nine months 2026 |
|---|---|---|
| Opening cash | 846 | 1,434 |
| Operating cash flow | +5,177 | +8,137 |
| Investing cash flow | −2,423 | −6,258 |
| Financing cash flow | −2,323 | −2,905 |
| Currency effects | +1 | +5 |
| Closing cash | 1,278 | 413 |
Source: Third-quarter Form 10-Q, cash-flow statement, p. 9. For 2026, investing includes $581 million acquired with Coterra, $96 million of disposal proceeds, $32 million of investment distributions and $107 million of investment contributions, alongside capital spending and acquisitions. Financing also includes $8 million of finance-lease repayments and $80 million of employee-share withholding and other payments.
Calculation notes: To reconcile profit to operating cash, add back costs that did not use cash in the period, remove noncash gains, then account for collections and payments. The derivative row leaves actual hedge settlements in operating cash.
| Profit-to-operating-cash reconciliation; USD millions | First nine months 2025 | First nine months 2026 |
|---|---|---|
| Consolidated net earnings | 2,119 | 3,039 |
| Depreciation and depletion added back | +2,705 | +4,004 |
| Noncash derivative losses added, or gains removed | −111 | +843 |
| Deferred income-tax expense | +322 | +297 |
| Share-based compensation | +77 | +144 |
| Property impairments | +254 | 0 |
| Leasehold impairments and liability accretion | +26 | +38 |
| Asset-disposal gains removed | −342 | −24 |
| Other net adjustments | −62 | −172 |
| Changes in operating assets and liabilities | +189 | −32 |
| Operating cash flow | 5,177 | 8,137 |
Source: Third-quarter Form 10-Q, p. 9 and Note 10, p. 20.
Devon’s adjusted cash measure removes payment-timing movements and selected merger costs:
| Company-adjusted cash reconciliation; USD millions | Second quarter 2026 | Third quarter 2026 |
|---|---|---|
| Reported operating cash flow | 3,674 | 2,808 |
| Remove changes in operating assets and liabilities | −924 | +657 |
| Add cash restructuring and transaction costs, net of tax | +174 | +41 |
| Adjusted operating cash flow | 2,924 | 3,506 |
| Capital spending incurred, excluding acquisitions | −1,269 | −1,496 |
| Adjusted free cash flow | 1,655 | 2,010 |
Source: Third-quarter supplemental tables, p. 12. Adjusted amounts are non-GAAP. Merger-cost addbacks reflect current tax effects and nondeductible costs. Actual third-quarter capital payments were $1,464 million; $2,808 million less $1,464 million equals $1,344 million of cash-based free cash flow.
The equity reconciliation distinguishes shares issued, shares bought back and shares retired:
| Equity account; USD millions | December 31, 2025 | Net change | September 30, 2026 |
|---|---|---|---|
| Common stock at par | 62 | +52 | 114 |
| Additional paid-in capital | 5,388 | +24,285 | 29,673 |
| Retained earnings | 10,200 | +2,152 | 12,352 |
| Accumulated other comprehensive loss | −122 | +3 | −119 |
| Treasury stock | 0 | −7 | −7 |
| Total equity | 15,528 | +26,485 | 42,013 |
Calculation notes: Paid-in capital records amounts assigned to issued shares. Its increase comprises $24,893 million from the merger and $144 million of share compensation, less $751 million from retiring shares and a $1 million repurchase entry.
Common stock at par increased $53 million from merger shares and fell $1 million through retirements. Retained earnings increased by $3,039 million of profit less $887 million of dividends.
Treasury stock records $759 million of purchases offset by $752 million transferred when shares were retired. The $3 million change in other comprehensive income relates to pension accounting, after tax.
Source: Third-quarter Form 10-Q, equity statement, p. 10, and Note 9, p. 20. Retiring shares removes them from issued shares and transfers their recorded cost out of treasury stock; it does not use cash a second time.
Calculation notes: Issued shares reconcile, in rounded millions, as 622 opening shares plus 532 merger shares plus 4 restricted-stock grants, less 17 retired shares, equaling 1,141 closing shares.
Program repurchases were 15.135 million shares with a recorded purchase value of $686 million, while cash-flow repurchases were $680 million. The broader $760 million equity repurchase reduction and the retirement entries have a different scope from program-only purchases. These measures are not interchangeable.
Share-based compensation expense was $144 million, versus $77 million a year earlier; unrecognized compensation was $271 million, expected to be recognized over approximately two to two-and-a-half years depending on award type.
Source: Third-quarter Form 10-Q, pp. 9–10; Note 4, pp. 17–18; Note 17, p. 25.
Calculation notes: Assets reconcile to liabilities plus equity: $70,814 million = $28,801 million + $42,013 million at September 30, 2026; $31,599 million = $16,071 million + $15,528 million at December 31, 2025.
Contractual debt principal of $10,664 million plus $18 million of net premiums less $46 million of issuance costs equals the $10,636 million debt carrying amount. Annual coupon cost is the sum of each principal balance multiplied by its stated coupon, approximately $583.1 million. Lease liabilities and site-restoration obligations are analyzed separately from that financing-debt total.
Sources: Third-quarter Form 10-Q, balance sheet, p. 8; Notes 14–16, pp. 22–24. Devon uses successful-efforts oil-and-gas accounting; spending and subsequent depreciation do not disclose a maintenance-versus-growth capital split. See 2025 Form 10-K, Note 1, pp. 61–62.
Reporting basis: Research uses the November 11, 2026 New York cutoff, with substantive company evidence through November 6. Later developments were not established by the materials reviewed. Historical sources and management plans are dated beside their claims.
This report is for informational purposes and is not investment advice.