Devon Energy: Make every barrel count.

Imagine owning a productive gas well and discovering that the gas is worth less than nothing at the local trading hub. The geology worked. The drilling worked. The route to the customer did not. In the Permian Basin, where pipelines have struggled to keep up with production, periodically negative prices at Waha have made this an uncomfortable commercial reality.

That is a useful place to begin with Devon Energy. The company finds and produces oil, natural gas and natural gas liquids. But its recent decisions suggest a more interesting question than how much it can extract: how much of the value between the reservoir and the buyer can it keep?

01First, turn the drill sideways

Devon began in 1971 with John Nichols, his son Larry, five employees and no assets. Its early story was about assembling a business. Its consequential technical chapter arrived through another company: Mitchell Energy, acquired in January 2002.

The payment was substantial: about $1.6 billion in cash and 30 million Devon shares. Mitchell brought a position in the Barnett Shale and years of work making shale gas commercially recoverable. Devon then experimented with horizontal drilling to reach beyond the favorable geology that had supported Mitchell’s vertical wells.

The encouraging pilot results changed the development plan. By 2004, Devon was expanding horizontal drilling into more complex Barnett acreage. In 2007 it drilled its thousandth horizontal well. The breakthrough came from combining techniques and widening the territory where they could pay. That is a more useful account of innovation than the lone inventor waiting for inspiration.

“When we started, the vision was to build a U.S. oil and gas powerhouse.”Larry Nichols · co-founder · 2021

02Who actually buys a barrel?

Devon operates upstream, supplying the businesses that move, process and consume hydrocarbons. Its commercial customers include refiners, gas purchasers and commodity marketers. Natural gas liquids feed fuel and petrochemical markets. Households usually encounter the results through other companies, several transactions away from the well.

The business earns money by selling production, alongside marketing and midstream activity. In 2025, Devon reported $17.188 billion in total revenue, including $11.223 billion of oil, gas and NGL sales. Those figures describe the business before the Coterra merger; treating them as a full year for today’s combined company would distort the comparison.

Its expertise spans geology, reservoir engineering, drilling, completions and the commercial arrangements that move production. Rival producers such as EOG Resources, Diamondback Energy and ConocoPhillips compete for acreage, capital and technical talent. Devon’s case rests on its particular combination of rock, operating knowledge and infrastructure access. Customers still care about price and reliable delivery.

03Buy scale. Then get selective.

On May 7, 2026, Devon completed its all-stock merger with Coterra. Each Coterra share became the right to receive 0.70 Devon shares. Former Devon holders owned approximately 54 percent of the combination; former Coterra holders owned 46 percent. The company kept Devon’s name and stock ticker, DVN, and moved its headquarters to Houston while retaining a significant Oklahoma City presence.

The announcement valued the combined enterprise at approximately $58 billion using January 30 share prices. That was a combined valuation, rather than a cash acquisition bill. Management identified $1 billion in annual pretax synergies. Savings of that size remain an execution target, with a year-end 2027 run-rate timetable, rather than money already banked.

Then came subtraction. In October, Devon agreed to sell its Eagle Ford assets to Crescent Energy for $4.2 billion in cash. The assets represented roughly 4 percent of total oil-equivalent production. Management described the price as above its internal case for keeping them. Closing was expected around year-end 2026, subject to approvals and customary conditions. Bigger, in this strategy, still leaves room to sell.

04The expensive part between here and there

The Delaware Basin anchors this approach. In May 2026, Devon announced a roughly $2.6 billion purchase of 16,300 net undeveloped acres in New Mexico. The attraction was specific: acreage beside existing operations, opportunities for longer horizontal wells, and facilities already nearby. Adjacency can change development economics in ways that an acreage total conceals.

In August, Devon committed to the Solitude Pipeline System, a WhiteWater-led venture in which it would hold 25 percent. The planned system connects the Permian to Katy, Texas, with initial capacity of approximately 2.25 billion cubic feet daily in the second half of 2029 and another similar phase in 2030, subject to approvals. The aim is to improve access to Gulf Coast demand.

The lesson travels beyond energy: find the constraint that makes good production less valuable, then decide whether to own it, contract for it or work around it. A factory waiting for freight capacity would recognize the problem immediately.

05Water has a second shift

Water provides another example. Devon reported using nearly 95 million barrels of recycled water in 2024, representing 59 percent of water used in drilling and completions. That is a historical companywide measure, not a claim about every well or the newly merged portfolio. Storage basins and connecting pipelines allow water to return to operations and reduce dependence on truck movements.

There is a wonderfully practical detail in Oklahoma: Devon gives Iofina Resources access to produced water so it can extract iodine, return the water and pay Devon a royalty. A waste stream becomes somebody else’s feedstock. The attractive idea is the extra use extracted from something the company already has to handle.

06The discipline has to survive the price

Devon’s stated culture emphasizes integrity, relationships, courage and results. Those words become testable in field safety, water management and decisions about where capital goes. Its June 2026 outlook targeted returning up to 70 percent of free cash flow through dividends and repurchases. “Up to” matters: the policy depends on cash generation and board decisions.

The strategy has conditions. Lower commodity prices can overwhelm operating improvements. Pipelines need approvals and years of construction. More infrastructure also means more capital exposed to future demand. Water disposal restrictions, emissions requirements and merger integration add their own constraints. The reader can copy the habit of measuring the entire route to the customer. Copying Devon’s ownership structure requires its capital, geology and tolerance for commodity cycles.