Key Takeaways
The record-setting May 2026 federal lease sale demonstrates strong demand for select acreage in areas where quality inventory is increasingly scarce, but headline prices should not necessarily be interpreted as representative of broader acreage values across the Permian or other basins.
Premium acreage values are driven by strategic factors beyond just geology, including drilling inventory, contiguous acreage positions, infrastructure access, development flexibility, favorable lease terms, and operator-specific synergies that can justify significantly higher bids.
Federal lease sale results can be a useful market indicator but should be evaluated alongside other valuation evidence (including market A&D, well performance, development costs and timing, commodity price assumptions, and royalty burdens) to accurately assess upstream asset values.
In May 2026, the Bureau of Land Management generated over $4.0 billion in total receipts from an oil and gas lease sale in New Mexico and Texas, the largest onshore federal oil and gas lease sale in U.S. history and roughly four times the prior record of $972 million set in 2018.
The May sale covered 74 parcels totaling approximately 33,530 acres, implying an average of roughly $120,000 per acre.
That figure is striking, but it is best read as a reminder of a familiar theme in upstream valuation: not all acreage is created equal.
The headline number is best read as evidence of strong demand for one class of inventory: it captures pricing for high-quality, strategically located acreage, and says less about broader federal, Permian, or Delaware Basin acreage values.
That sale followed a notable result earlier in the year: in January 2026, the BLM leased 31 parcels totaling approximately 20,399 acres in New Mexico and Oklahoma for nearly $327 million. Together, the two suggest that operator appetite for select acreage is robust, particularly near established development areas.
Scarcity Value in Core Inventory
Acreage value is fundamentally tied to the expected future cash flows from the leasehold, and in unconventional plays that value is often driven by drilling inventory.
Each bid represents a potential drilling location, operating control, development flexibility, and future production optionality.
This helps explain the relative premium that core inventory has carried in recent years.
As large E&Ps have consolidated positions across major basins, the availability of high-quality, scalable acreage has declined, while disciplined capital allocation has kept management focused on balancing growth against shareholder returns. In that environment, adding lower-risk inventory can be worth a premium, with the strongest bids tied to contiguous blocks, stacked-pay potential, nearby infrastructure, and confidence in well productivity. This broader theme in upstream M&A was described by our colleague Bryce Erickson, Managing Director at Mercer Capital, in a recent article, The Pendulum Is Swinging: Reserve Life Matters Again.
Lease sale data should also be interpreted differently than corporate or asset-level M&A data: a bonus bid can carry strategic value specific to a nearby operator, so the same acreage may be worth different amounts to different bidders depending on adjacency, infrastructure access, and internal views on well performance.
Devon’s Delaware Basin Purchase as a Public Marker
The clearest example from the May sale was Devon Energy’s acquisition of approximately 16,300 net undeveloped acres in the Delaware Basin in Lea and Eddy Counties, New Mexico, for approximately $2.6 billion, or about $161,500 per net acre.
That price is best understood as a public marker for what a motivated, strategic buyer will pay for acreage that fits its footprint, with limited read-through to undeveloped Permian acreage broadly.
For an existing operator, adjacent acreage can improve drilling efficiency, enable longer laterals, support shared infrastructure, and add depth to an already staffed, permitted, and capitalized development schedule. Those synergies are not equally available to all participants, supporting pricing above what another buyer would pay.
Lease Economics and Royalty Rates
Lease terms also matter.
These sales occurred after the federal royalty rate for new onshore production was reset to a minimum of 12.5%, reversing the 16.67% minimum established under the Inflation Reduction Act. Devon’s transaction shows the effect directly: it reported that its new federal leases carry an 87.5% net revenue interest with 10-year terms, more favorable than typical state and private (fee) leases, and cited the lower royalty burden as immediately accretive to its inventory.
A lower royalty burden increases the operator’s net revenue interest, all else equal, leaving a larger share of production revenue with the working interest owner and supporting higher value for undeveloped acreage. The impact is not uniform. It matters most where acreage is otherwise economic and likely to be developed, and far less for a parcel with marginal geology, no infrastructure access, or timing uncertainty.
The recent results are best viewed as a combination of geology, location, market structure, and lease economics, not the product of lower royalty rates alone.
Bifurcation Across Basins and Acreage Quality
The sales highlight a continued, and increasingly pronounced, bifurcation in acreage values.
Core acreage with near-term development potential, known productivity, and infrastructure access can command premium pricing (the highest single-parcel bid in the May sale reached approximately $357,000 per acre).
Non-core, less-delineated, gas-constrained, or infrastructure-short acreage may trade at a substantial discount.
As operators focus on capital efficiency, acreage that cannot compete for capital may have limited value even where hydrocarbons are present, while acreage that generates attractive returns at conservative price assumptions can be highly competitive, particularly if it fills a gap in an existing program.
Acreage values reflect the weight buyers give to future prices, basis differentials, service costs, regulatory risk, development timing, and capital availability. In the Permian, even strong acreage can face pressure if gas-handling constraints or weak local gas pricing delay development.
Interpreting Lease Sale Data
Lease sales are valuable because they represent observable market activity, but they require careful interpretation.
A bonus bid generally reflects the right to lease and develop under specified terms and is not indicative of the ownership of proved developed production or existing cash flow.
For valuation purposes, lease sale data should be triangulated with other evidence including comparable A&D transactions, public company disclosures, well performance and type curves, development and operating costs, commodity price and differential assumptions, royalty burdens, and timing to first production, all of which are factors in attracting capital and generating competitive returns.
Conclusion
Recent BLM lease sales show that the market continues to assign significant value to increasingly scarce, high-quality oil and gas acreage, with the strongest bids tied to core Permian inventory, strategic fit, development visibility, and improved lease economics.
The headline values are not broadly indicative. Quality here is narrow, defined by location, development timing, infrastructure, operator fit, and capital efficiency.
The results largely reflect demand for limited high-quality inventory and not necessarily broad-based appreciation across all acreage classes.
Mercer Capital has assisted many clients with various valuation needs in the oil and gas industry in North America and globally. In addition to our corporate valuation services, Mercer Capital provides investment banking and transaction advisory services to a broad range of public and private companies and financial institutions. We have relevant experience working with companies in the oil and gas space and can leverage our experience to help you navigate a critical transaction, providing timely, accurate, and reliable results. Contact a Mercer Capital professional to discuss your needs in confidence.