How to Value Permian Basin Mineral Rights

If you have received an unsolicited offer for your Permian Basin mineral rights — or if you are simply curious what your acreage might be worth — understanding how valuation actually works is the most important thing you can do before any transaction. Mineral rights buyers and sellers often talk past each other because they are not using the same framework. This guide explains, step by step, how experienced buyers evaluate Permian Basin mineral interests.

Start With Net Mineral Acres (NMA)

The foundational unit of mineral rights valuation is the net mineral acre (NMA). Your gross acreage is the total surface acreage of the tract — for example, a 640-acre section. Your net mineral interest is your fractional ownership of the minerals beneath that tract. If you own a 1/8 mineral interest in a 640-acre section, you own 80 net mineral acres (640 × 1/8 = 80 NMA).

This sounds simple, but mineral ownership is often fragmented across many generations of inheritance. Many mineral owners do not know exactly how many NMA they own. Your county deed records, a mineral rights title company, or an experienced buyer like ARB can help you determine your exact interest.

Producing vs. Non-Producing Acreage

The single largest driver of mineral rights value is whether there is active production beneath your acreage. Producing acreage — where there are existing horizontal wells generating monthly royalty income — is valued primarily on a production multiple basis. Buyers look at your trailing 12-month royalty income, apply a discount rate to account for well decline, and arrive at a present-value figure.

Non-producing acreage — where there are no wells yet — is valued on a per-NMA basis that reflects the probability and timing of future drilling. In the core of the Permian Basin — including high-activity counties like Midland County and Howard County in the central Midland Basin, and the southern Delaware Basin — that probability is high and the per-NMA price reflects it. On the edges of the basin or in less-proven areas, the discount is larger.

How Well Decline Affects Value

Permian Basin horizontal wells are prolific, but they decline rapidly. A typical Wolfcamp or Bone Spring well produces 60–80% less in its second year than in its first. Buyers price this into every offer. If your acreage is producing from a well that was drilled two years ago, the royalty income you are receiving today will likely be significantly lower in two to three years — which is precisely why many mineral owners choose to monetize at peak production rather than wait through the decline curve.

Operator Tier and Drilling Inventory

Who is operating on your acreage matters enormously. A Pioneer Natural Resources, ConocoPhillips, or Diamondback Energy permit on your section commands a premium because investors know those operators will execute efficiently, drill the optimal number of laterals, and maximize recoverable reserves. Smaller or less well-capitalized operators introduce execution risk that buyers discount.

Equally important is the drilling inventory beneath your acreage — how many remaining horizontal locations exist that have not yet been drilled. A section with three producing wells but estimated capacity for twelve more is worth considerably more than one that appears fully developed. Buyers use public spacing unit data, formation maps, and operator filings to estimate remaining inventory.

Commodity Price and Macro Factors

Mineral rights valuations are also influenced by the current price of oil and natural gas. When WTI crude is above $70–80/bbl and operators are actively deploying capital, buyers pay more because the underlying economics of the assets are stronger. When prices fall or operators pull back, per-NMA prices compress. The Permian Basin is generally the last place operators cut activity because of its superior economics — which is one reason Permian Basin mineral rights tend to hold their value better than other plays during downturns.

The Valuation Methods Buyers Use

Experienced buyers use three primary methods, often in combination:

• Production multiple: For producing acreage, buyers calculate annualized royalty income and apply a multiple (typically 30–60× monthly income for top-tier Permian acreage), adjusted for decline.
• Comparable sales: Buyers track per-NMA prices from recent transactions in the same county or formation, which provides a market-based anchor.
• DCF (discounted cash flow): For larger or more complex interests, buyers model future production under various price scenarios and discount back to present value at their required return rate.

The specific combination of methods depends on your acreage location, production status, and the complexity of your mineral interest.

How ARB Prepares an Offer

ARB is a direct buyer that acquires mineral interests with its own capital. When you contact ARB, our team evaluates your interests using all of the methods above, pulls the most recent production and permit data from the Texas Railroad Commission and New Mexico OCD, and delivers a transparent offer within five business days.

There are no fees, no commissions, and no obligation. If our offer is not right for you, you keep it as a useful data point for any future transaction.