Permian Basin Mineral Rights

No basin in the country moves a valuation multiple faster than the Permian, and no basin punishes a lazy county-blind estimate harder either.

The Permian splits into two working basins under one regional name, the Midland Basin on the eastern side and the Delaware Basin to the west, separated by the Central Basin Platform. Wolfcamp, Spraberry, and Bone Spring intervals stack on top of each other across dozens of counties, and an operator can drill several of those benches from a single pad. That stacked-pay reality is exactly why Permian multiples tend to run ahead of most other US plays, but it's also why a valuation has to know which county, which formation, and which operator footprint an interest sits under before it means anything.

Midland vs Delaware Isn't a Minor Detail

Midland County, Martin County, and Howard County sit in the Midland Basin core, where Wolfcamp A and B benches have produced consistently for well over a decade and operator activity is dense enough that comps update constantly. Reeves, Loving, and Culberson counties sit in the Delaware Basin, generally deeper, higher pressure, and more expensive to drill, but with thicker stacked pay in the Bone Spring and Wolfcamp that can support more future wells per section.

An interest in Midland County core acreage and an interest in a Delaware County flank position can carry meaningfully different multiples even at similar trailing revenue, because the stacked-pay depth and remaining undrilled locations differ. Any valuation quoting a single flat Permian multiple regardless of county is skipping the input that matters most here.

Operator Concentration Drives the Comp Set

Consolidation has left a handful of large operators controlling most Permian acreage, Diamondback Energy, Occidental, ConocoPhillips, EOG, and Exxon's Permian subsidiaries among them. That concentration is actually useful for valuation purposes, because it narrows the comp set to a manageable list of well-documented operators with public rig counts and permitting activity by county, rather than dozens of small private operators with opaque plans.

Watching which operator holds the offset acreage around a specific interest tells you a lot about near-term drilling likelihood. A section surrounded by an active operator's current rig program supports more risked upside in the valuation than the same acreage held by an operator that has gone quiet in that county.

Stacked Pay Changes the Upside Math

Because Wolfcamp, Spraberry, and Bone Spring can each support their own horizontal wells from the same surface location, a Permian valuation needs to account for how many benches remain undeveloped under a given tract, not only what's currently producing. Trailing revenue only reflects the wells already online, so the risked-upside component of the framework carries more real weight here than in single-bench basins.

That said, more remaining benches doesn't automatically mean a bigger number. Spacing and well interference between stacked laterals have become real constraints operators actively manage, so undeveloped bench count should be discounted against current spacing practice in that specific county, not treated as unlimited future locations.

Rig Count and Commodity Price Sensitivity

Permian multiples move with oil price and rig count more visibly than in most basins, simply because so much US drilling activity is concentrated there. A multiple that held during a high-rig-count stretch can compress when operators pull back capital spending, which is why comps older than twelve to eighteen months should be treated with caution here specifically.

This cuts both directions for owners. An interest valued during a strong activity stretch can look better than one valued during a pullback even with identical underlying production, which is part of why timing a sale against current comps, not last year's headlines, matters more in the Permian than almost anywhere else.