Devon Energy (DVN) Q3 2026 Earnings Call: Q&A Summary

Q: Doug Leggate from Wolfe Research asked whether the conclusion of the portfolio review signals the end of portfolio high-grading, and inquired about the alternatives explored.

A: Clay Gaspar, President and Chief Executive Officer, explained that the review was a comprehensive and transparent evaluation using perspectives from both Devon and Coterra. While they entertained various external ideas and concluded that chapter with the current portfolio, they remain objective and open to future transactions that serve shareholder interests.

Q: Neil Mehta from Goldman Sachs asked how management interprets the stock's underperformance since the merger and what is being done to build market confidence.

A: Clay Gaspar acknowledged the dissatisfaction with share performance and stated that investors are looking for clarity on the pro forma company's identity and strategy, which the newly articulated three-pillar plan aims to provide.

Q: Arun Jayaram from JPMorgan asked about the perceived gap in intrinsic value and how the company plans to use buybacks to address the stock dislocation.

A: Clay Gaspar and Shane Young, Chief Financial Officer, noted that shareholders missed a clearly articulated strategy and reiterated that Devon sees compelling value in its shares, planning to lean heavily into share repurchases, including over $1 billion in the fourth quarter.

Q: Devin McDermott from Morgan Stanley asked about synergy delivery speed, milestones for next year, and potential upside to the $1 billion target.

A: Blake Sirgo, an executive, highlighted fast-moving integration, noting that AI tools increased simultaneous fracturing from 68% to 75%, lateral lengths are rising over 10%, and expected drilling and completion costs are around $750 a foot for 2027.

Q: Betty Jiang from Barclays asked how leasehold ground game investments are underwritten and how they compare to drilling or buybacks in replenishing inventory.

A: Trey Lowe, an executive, responded that ground game investments compete directly against drilling, infrastructure, and other uses on a PDI, rate of return, and net present value basis, and the Midland-based growth team continues to find highly productive opportunities.

Q: Neal Dingmann from William Blair asked about the types of non-E&P ventures and midstream investments being evaluated under organic opportunities.

A: Clay Gaspar explained that investments like the Solitude pipeline allow Devon to capture full-cycle returns by resolving gas constraints in the Delaware Basin, and all such projects must compete on a fully risked basis against traditional horizontal drilling.

Q: Phillip Jungwirth from BMO asked why the presented 2027 portfolio outlook is a better long-term outcome than what could be achieved with less scale.

A: Clay Gaspar stated that scale, inventory depth, and synergy transfer enable multiyear value creation, noting that the Eagle Ford was divested because its steep base decline and maintenance capital made its peak value a rear-view mirror event.

Q: Scott Gruber from Citigroup asked how to rank the key drivers behind delivering low single-digit growth with flattish capital.

A: Clay Gaspar and Shane Young noted that the strategy is driven by inventory longevity, the Coterra merger synergies, and the federal lease sale, all supported by durable economics down to $60 to $70 a barrel oil.

Q: Joshua Silverstein from UBS asked about the value of the Marcellus asset and its role in the portfolio given expected gas growth in the Permian.

A: Clay Gaspar described the Marcellus as a coveted asset with exceptional upside value driven by operational and digital technology integration, while leadership remains objective regarding all assets.

Q: John Freeman from Raymond James asked about lateral length progress and its impact on cost per foot for the Delaware program in 2027.

A: Blake Sirgo stated that the company is pushing limits in long laterals, including 53 four-mile wells planned for next year utilizing creative well geometries like 2x2 turns to drive down cost per foot.

Q: Christopher Baker from Evercore ISI asked about the strategic value of the Anadarko and Rockies assets.

A: Clay Gaspar highlighted significant synergy potential and midstream opportunities in the Anadarko, and operational improvements and long laterals driving free cash flow in the Williston and Powder River basins.

Q: Gabe Daoud from Truist asked about Permian inventory and testing in deeper zones like the Woodford and Penn Shale.

A: Trey Lowe responded that the company continues to appraise deeper zones while prioritizing co-development and incorporating the newly acquired BLM lease acreage into the program.

Q: Matt Portillo from TPH asked about the Permian oil cut outlook and whether gas production will keep pace with industry takeaway capacity.

A: Clay Gaspar noted that while the inventory is driven by oil economics, the natural gas-rich environment and upcoming infrastructure like the Solitude pipeline will eventually unlock high-margin gas realizations without forcing a premature shift away from oil.

Q: Kevin MacCurdy from Pickering Energy Partners asked about the increased ground game spending planned for 2027 and how it differs from past run rates.

A: Clay Gaspar and Trey Lowe explained that the $500 million ground game plan for next year reflects strong synergy capture from the combined Midland office, generating full-cycle returns with per-stick acquisition costs of roughly $2 million to $3 million.