Sell Mineral Rights in North Dakota

North Dakota has more comparable sales data than almost any other mineral state, which is both a gift and a trap: the numbers are out there, but a lot of them don't apply to your specific quarter section.

The Bakken and underlying Three Forks formation made McKenzie, Mountrail, Dunn, and Williams counties some of the most closely watched mineral markets in the country. Over more than fifteen years of horizontal development, spacing units have tightened, multiple benches within the Three Forks have been targeted separately, and enough wells have been drilled that buyers can model your specific section with real data rather than a guess. That's the good news. The complicating news is that with this much drilling history, well density and spacing on your exact tract matter enormously, and a number from a neighboring county, or even a neighboring section, can be misleading.

Well Density and Spacing Units Drive the Number

In a mature core-Bakken county, the single biggest driver of value is how many wells are producing, permitted, or planned within your spacing unit, and which bench they target. A quarter section with four producing Middle Bakken wells and additional Three Forks laterals permitted is a fundamentally different asset than one with a single older well and no further development planned. North Dakota's Industrial Commission publishes spacing order and permit data by section, which is exactly the kind of documentation a serious buyer will want to see alongside your division order.

Because the play is mature, 'undeveloped' acreage is rarer here than in a newer basin — most core-Bakken minerals have at least some production history. When that's true, your own royalty statements, not a general county average, are the best starting point for a conversation.

Reading Your Division Order Decimal

North Dakota spacing units are typically 1,280 acres for two-mile laterals, and your royalty decimal reflects your net mineral acres divided across that whole unit — often shared among many other owners. It's common for owners to underestimate or overestimate what they actually hold until they see the decimal spelled out. Before valuing anything, confirm your net mineral acres from the deed and cross-check the decimal on your most recent division order; a mismatch between the two is worth resolving before you negotiate a sale.

If multiple wells target your unit from different benches, you may see more than one division order over time, each adjusting your interest slightly as new units are formed. Keep every version — a buyer will want to see the progression over time, beyond only the latest one.

Oil Price and Decline Curve

Bakken wells follow a fairly well-documented decline pattern: a strong initial 12-18 months followed by a longer, gentler tail. Where your specific wells sit on that curve matters a great deal. A well still in its first year of production is priced very differently than one ten years into its tail, even with similar current monthly volumes, because the newer well still has more of its productive life ahead of it.

Layered on top of the decline curve is oil price itself, which moves faster than any geologic factor and shifts quoted ranges from quarter to quarter. Any number you're offered should reflect current pricing and your wells' actual position on the curve, not a flat historical average.

What Raises or Lowers an Offer

Offers tend to run higher for interests with several producing wells, recent permits for additional laterals nearby, a clean and confirmed net mineral acre figure, and a straightforward chain of title with no unresolved heirship. They tend to run lower for single older wells well into decline, small fractional interests, or title that still needs to be cleared through probate. None of that is unique to North Dakota, but because the Bakken has this much documented history, buyers here can be more precise about which of those factors applies to you than in a less-drilled state.