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Devon Energy develops oil and gas fields in the United States, with the Delaware Basin supplying most of its production and receiving the largest share of investment. It drills wells and sells the oil, natural gas and natural gas liquids they produce under short- and long-term agreements. Buyers pay mostly prices that move with commodity markets, so longer contracts do not generally lock in Devon’s selling prices.
Keeping production going requires investment in new wells and reserves as existing wells decline. Devon also relies on other companies’ facilities to process gas and move production to buyers; limited access can force it to reduce output. Conservation rules can restrict well locations and production volumes, while permitting requirements and limits on wastewater disposal can constrain development.
The risk section is the longest, dullest part of the filing. This keeps only what can really hurt you: where it hits, how hard, when it plays out.
Every company claims an edge. Each one is checked against hard numbers like margins and returns: which hold, and which line gives way first.
Diamondback Energy shares Devon’s exposure to Permian oil prices and drilling costs, with both producing oil and gas from overlapping Delaware Basin formations. Watch Diamondback’s Delaware development costs against Devon’s largest, best-funded operating area.
Permian Resources and Devon both sell oil, gas and natural gas liquids from core Delaware Basin acreage, tying their sales to similar commodity markets. Permian Resources’ prices received are worth watching: it generally sells at market prices even though most revenue contracts run longer than 12 months.
EOG Resources and Devon sell the same oil, gas and natural gas liquids and operate in overlapping U.S. areas, including the Powder River Basin. EOG’s drilling and operating costs offer a comparison for Devon’s U.S. development, though EOG also produces abroad.
Occidental and Devon both sell oil, gas and natural gas liquids, with shared operating exposure in the Permian and Powder River basins. Occidental’s Permian field-development results are a closer comparison for Devon than its broader international and other businesses.
Matador Resources and Devon both direct development spending toward oil- and liquids-rich Delaware Basin resources. Watch Matador’s drilling and well-completion spending there, separating it from revenue earned by processing gas and moving oil and water for other producers.
Ovintiv and Devon produce and sell oil, gas and natural gas liquids in overlapping Permian and Anadarko regions, exposing both to similar prices and development costs. Ovintiv’s U.S. operating results are the closer comparison; its Canadian business includes the Montney.
ConocoPhillips and Devon both sell crude oil, gas and natural gas liquids at market-sensitive prices, so commodity-price changes reach both businesses. Watch ConocoPhillips’ prices received rather than treating its broader international production portfolio as a direct match for Devon’s U.S. onshore operations.
Chord Energy offers a comparison for Devon’s Williston oil, gas and natural gas liquids business, which became significant after the 2024 Grayson Mill acquisition. Watch the regional and transportation adjustments in Chord’s oil sales to refiners and marketers: they show how local conditions affect prices received.
APA and Devon both rely materially on Permian production and cash flow from selling oil, gas and natural gas liquids. APA’s drilling and well-completion costs there provide a useful comparison for Devon’s heavily funded Delaware Basin program.
SM Energy and Devon both earn revenue selling oil, gas and natural gas liquids from U.S. onshore assets, with exposure to the Permian and South Texas. Oil supplied 82% of SM Energy’s production revenue in 2025, making its oil-sales results particularly relevant to Devon’s oil-focused areas.
Northern Oil and Gas shares Devon’s exposure to Williston and Permian well costs and oil-and-gas returns, but funds a share of wells run by other operators rather than running them itself. Watch how many proposed wells it chooses to fund: it says lower oil prices typically reduce both proposals and its participation.
Magnolia Oil & Gas and Devon both produce oil, gas and natural gas liquids in the Eagle Ford region and use production cash flow to fund drilling and shareholder returns. Watch Magnolia’s cash left after drilling and completing wells as a comparison for the balance between reinvestment and payouts.
Crescent Energy and Devon both generate cash flow from oil, gas and natural gas liquids production, but Crescent emphasizes acquisitions and assets whose output declines more slowly. Its spending to maintain production is the useful comparison for Devon, rather than assuming the two need the same reinvestment.
Devon pays WaterBridge Infrastructure to collect, transport and handle water produced alongside oil and gas, helping keep production flowing. Watch its Delaware Basin water-handling reliability: WaterBridge says producers may have to shut in wells when pipeline capacity is constrained and reliable water handling is unavailable.
Devon rents compressors from Natural Gas Services Group to help lift oil from wells using compressed gas; Devon and Occidental together supplied 59% of its revenue in each of 2025 and 2024. Watch rental-equipment reliability and unplanned shutdowns for clues about this part of Devon’s production support.
ExxonMobil competes with Devon in producing and selling Permian oil and gas, but its refining, chemicals and international businesses make company-wide results a less direct comparison. Focus on its Permian development news rather than its overall earnings.
Devon pays EagleRock Land for access to land and resources supporting its Permian operations, contributing more than 10% of EagleRock’s pro forma total revenue for 2025. Watch fees for drilling sites, roads, pipelines and water use as a view into the surface infrastructure supporting Devon’s activity.
EIA Crude Oil Stocks Change (Oct/16)
US crude and gasoline stock levels show whether oil and fuel supplies are building or drawing down, which can shift the market-sensitive prices Devon earns when it sells its oil, gas and NGLs.
Read a stock build as a sign that oil and fuel supply may be loosening, which can weigh on the prices Devon receives for its production; a stock draw may signal tighter supply and support those prices.
EagleRock Land, LLC earningsEROK
EagleRock Land's report offers a read on whether demand is changing for the land access and site services that support Devon Energy's Permian operations.
Watch how EagleRock Land's land-access and site-service business performs. Strength would be consistent with steady demand for drilling sites, roads, pipelines or water use; weakness could point to less activity or fee pressure. EagleRock also serves other customers, so its overall results do not directly measure Devon's spending.
Crescent Energy Company earningsCRGY
Crescent Energy's report will show what it spends to maintain production, a qualified comparison for Devon Energy's reinvestment burden.
Read Crescent's spending to maintain production alongside its output. Lower spending with stable production would suggest its assets need less capital to sustain output; higher spending could signal a heavier maintenance burden. Its assets decline more slowly than Devon's, however, so this is a reference point for reinvestment needs, not a like-for-like comparison.
Diamondback Energy, Inc. earningsFANG
Diamondback Energy's report will show whether drilling and completion costs are changing in the Delaware Basin, where Devon Energy has its largest program.
Watch Diamondback's Delaware Basin drilling and completion costs alongside its activity. Lower costs would suggest less local pressure on development economics, which could help Devon's largest program; rising costs could weigh on returns from Devon's new wells. The companies' wells and plans differ, so their costs are not directly interchangeable.
Chord Energy Corporation earningsCHRD
Chord Energy's report will show how local sales and transport factors affect oil prices in the Williston area, relevant to Devon Energy's Rockies production.
Read the regional and transportation adjustments in Chord's oil prices alongside its benchmark price. More favorable adjustments would suggest less local drag on prices; worsening adjustments could weigh on Devon's proceeds from Williston production. Their sales routes and oil mix may differ, so this is a regional price signal, not a direct substitute for Devon's realized price.
Permian Resources Corporation earningsPR
Permian Resources' report will show how realized oil, gas and NGL prices are moving in the Delaware Basin, Devon Energy's largest producing area.
Read Permian Resources' realized prices separately for oil, natural gas and NGLs rather than blending the products. Stronger prices would point to a more favorable market for Devon's largest producing area; weaker prices could pressure its sales revenue. Devon's product mix and hedges differ, so its own realized prices will settle the question.
WaterBridge Infrastructure LLC earningsWBI
WaterBridge Infrastructure's report will show whether produced-water handling and transport in the Delaware Basin are running smoothly, a link in keeping Devon Energy's wells producing.
Watch what WaterBridge says about produced-water capacity and reliability in the Delaware Basin. Smooth service would support Devon's ability to keep wells producing; constraints or outages could force producers to curtail or shut in wells. WaterBridge's overall results cannot prove Devon was affected, so treat them as a warning signal from a supplier, not evidence of a Devon outage.
Devon Energy Corporation earningsThis company
Devon Energy's report will show whether changes in oil and gas prices and production costs are squeezing the cash its production generates.
Read field-level cash margin per Boe alongside production, then check realized prices for oil, natural gas and NGLs against production costs. A steady margin with production holding up would show Devon is still turning output into cash; a falling margin, even with more production, would show that prices, product mix or costs are eroding the benefit of added output.
