Midland Basin Mineral Rights

Midland Basin production has a longer track record than most of the Permian, and that history is exactly what a buyer reads before ever mentioning a number.

The Midland side of the Permian has been drilled harder and longer than the Delaware, and the counties at its core, Midland, Martin, Howard, Glasscock and parts of Reagan and Upton, have gone through vertical development, early horizontal Wolfberry wells, and now dense, multi-bench Wolfcamp and Spraberry development in the same sections. That layered history shows up in royalty statements as a mix of legacy production and newer high-rate wells sitting on the same lease.

We've operated in this basin and we've bought minerals in it, and the question we ask an owner first is whether their check reflects one well or a full pattern of wells drilled over multiple years. That distinction matters more here than almost anywhere else in the play, because it's the difference between a position near the end of its life and one still being actively developed around. We also want to know the API numbers involved if you have them, since two wells on the same lease can be at very different points in their own decline even when they were drilled around the same time.

Downspacing changed what checks look like

In the mid-2010s, operators in the Midland Basin moved from wide-spaced vertical wells to tightly spaced horizontal development, often four, six, or more wells per section targeting different Wolfcamp and Spraberry benches. For a mineral owner, that meant a single royalty check tied to one legacy well could suddenly become several checks as infill wells came online.

It also means production interference is a real thing operators manage and owners should expect. A new well drilled close to an older one can temporarily pull rate from the existing well as pressure equalizes between them. That shows up as a dip in an otherwise stable older well's check, and it's worth understanding rather than assuming something's gone wrong with the interest.

Wolfberry-era vertical wells drilled in the 2000s behave differently again, typically low-rate but very long-lived, and a lot of Midland Basin owners hold a mix of a legacy vertical well's royalty alongside newer horizontal wells on the same section, which means one statement can show two very different production personalities on the same page.

Core versus flank in Midland Basin terms

Martin and Midland counties, along with the northern part of Howard County, sit in what most operators consider the core of current Wolfcamp development, with dense drilling programs and multiple active operators running rigs. Move toward Glasscock's southern edge, or into Upton and Reagan, and you're closer to flank acreage where completions are thinner and less predictable.

That doesn't mean flank minerals are worth ignoring. Some of the steadiest, longest-producing legacy wells in this basin sit outside the current core, on leases that were drilled decades ago and have settled into a long, low-decline tail that a core-area buyer might actually undervalue if they only look at recent permit activity.

Reading your own decline before you talk to anyone

Pull your last two years of statements and look at the trend rather than only the most recent month. A Midland Basin well that's five or more years old and still throwing off a relatively flat check is behaving like a mature, de-risked asset, and that stability is worth something even without new drilling nearby.

If you see gaps, operator changes, or a sudden jump followed by a drop, that's usually a new well coming online and then settling, not a red flag. We'll walk through your specific statements with you and tell you plainly whether what you're seeing looks like normal Midland Basin behavior or something worth double-checking with the operator directly.