• BP (BP) is evaluating U.S. shale acquisitions worth roughly $2–5 billion, including a potential bid for Devon Energy (DVN)'s Eagle Ford assets, according to Reuters sources.
  • The move aligns with BP's strategy to simplify its portfolio while emphasizing higher-return oil-and-gas assets, though no agreement has been confirmed.
  • A successful deal would expand BP's onshore oil exposure and leverage its existing Eagle Ford operating experience.

BP is reportedly scouting U.S. shale acquisitions valued at $2–5 billion, with a possible eye on Devon Energy's Eagle Ford position, according to people familiar with the matter. The potential move comes as the London-based major pivots back to its oil-and-gas roots under new leadership, though the talks remain exploratory and no binding offer has been made.

The news, first reported by Reuters, underscores BP's appetite for shorter-cycle, oil-weighted assets that can quickly contribute to cash flow. Devon, meanwhile, is reviewing its Eagle Ford and Powder River Basin shale assets, which Bloomberg reported could collectively fetch more than $4 billion. Reuters noted on July 24 that a sale was under consideration, but Devon has not made a final decision and could retain the assets.

BP's interest is strategically credible given its existing footprint in the Eagle Ford. BPX Energy, the company's U.S. onshore subsidiary, has deep operating experience in the basin, having partnered with Devon in the Blackhawk Field for around 15 years before dissolving the joint venture in early 2025. That separation left Devon with about 46,000 net Eagle Ford acres, over 95% working interest, and operatorship—an attractive package for a buyer seeking operated, oil-rich inventory.

"This would not be BP's first transaction with Devon," a person familiar with the matter said, pointing to BP's 2015 acquisition of Devon's San Juan Basin properties in New Mexico. "The familiarity cuts both ways—it reduces integration risk but also means BP knows exactly what it's bidding on."

The potential deal fits BP's broader portfolio rotation. The company has been divesting non-core assets—including its Gelsenkirchen refinery, Austrian retail business, UK North Sea operations, and U.S. biogas business Archaea—to simplify operations and shore up its balance sheet. Under CEO Meg O'Neill, who took the helm on April 1, 2026, BP has consolidated into two primary units, upstream and downstream, effective July 2026, with a sharpened focus on operational reliability and capital discipline.

BP reported second-quarter 2026 underlying replacement-cost profit of $5.7 billion and operating cash flow of $10.9 billion, but upstream production slipped to 2.2 million barrels of oil equivalent per day from 2.3 million boe/d in the prior quarter amid planned maintenance and Middle East disruptions. Adding U.S. shale barrels could help offset such fluctuations.

Devon's perspective is equally pragmatic. The Oklahoma City-based independent has been concentrating its portfolio around the Permian/Delaware Basin, including a roughly $2.6 billion acquisition of 16,300 net undeveloped Delaware Basin acres in May 2026. Divesting Eagle Ford and Powder River assets would free capital and management attention for higher-priority Permian projects.

Industry analysts note that U.S. shale remains a bright spot for majors seeking scalable, short-cycle production. The Energy Information Administration projects 2026 U.S. crude production at 13.8 million barrels per day, above the 2025 record of 13.7 million b/d. WTI has averaged $84 per barrel through August, well above Permian breakeven levels of about $69/b in the Midland Basin and $63/b in the Delaware Basin, according to EIA data. Eagle Ford oil output is forecast near 1.1 million b/d through 2026.

"For BP, an oil-weighted Eagle Ford acquisition would add near-term production that complements longer-cycle international projects," said a Houston-based energy analyst who declined to be named. "The basin is mature, but it's still one of the most economic oil plays in the U.S."

Despite the strategic appeal, valuation risk looms. Shale wells decline rapidly, requiring continuous reinvestment to sustain output. Any transaction's value would hinge on proved developed reserves, undeveloped drilling inventory, well productivity, operating costs, midstream commitments, and commodity-price assumptions. The EIA expects Brent to slide below $80/b in the third quarter of 2026 and toward $70/b by year-end, a less favorable pricing environment than current spot levels.

Environmental considerations also linger. While the federal regulatory climate has grown more accommodating for domestic hydrocarbon production—Congress repealed the methane waste-emissions charge and EPA loosened some flare and vent-gas rules in 2026—state-level enforcement, litigation, and investor expectations around emissions remain factors. Proposed weakening of requirements for low-producing wells has already drawn criticism over methane-leak risks.

BP shareholders may welcome higher-margin cash generation if the company buys at a disciplined price, but they could resist a large purchase that raises debt or competes with buybacks and dividends. Devon shareholders, on the other hand, could benefit if a competitive auction crystallizes value for non-core assets.

BP and Devon both declined to comment on the reported talks. Efforts to reach Devon's financial advisors were unsuccessful.

The coming months will reveal whether Devon formally launches a sale process, whether BP submits a bid or walks away, and how the purchase price stacks up against oil-price expectations. For now, the reported interest signals that BP is willing to rotate capital into U.S. shale—provided the numbers work.

Correction: An earlier version of this article misstated the date of the Blackhawk Field joint venture dissolution. It was early 2025, not 2024.