North Dakota valuation
Bakken core economics, the heaviest production tax burden in the country, and a dormant mineral statute that can take an idle interest away entirely.
North Dakota mineral rights are worth what the Bakken and Three Forks will produce beneath the specific spacing unit your acreage sits in. The core counties — McKenzie, Williams, Mountrail and Dunn — carry the most valuable mineral positions in the state, and value drops off quickly outside that fairway toward Divide and Burke. Two North Dakota features move numbers more than owners expect. The state takes roughly 10% in combined gross production and extraction tax, the heaviest burden of any major producing state, which permanently reduces net royalty. And North Dakota has the most aggressive dormant mineral statute in the country: an interest unused for twenty years can be lapsed to the surface owner, so an idle North Dakota interest may be worth substantially less than its geology suggests, or nothing at all, if the lapse process has already run.
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What a mineral interest is worth comes down to what it will actually pay out over time, discounted for how long you wait and how sure the payment is. Production history, the formation, the operator, the tax the state takes, and whether anyone plans to drill again all move that number. The rules of thumb people repeat online — some multiple of a monthly royalty check — are anchors, not valuations. They ignore commodity prices, decline rates, operator quality and development potential, which is exactly where most of the value sits.
Pointer underwrites every tract individually rather than applying a published formula or a fixed multiple. When we send an offer we walk you through the specific factors that moved the number on your property, and if you think we got something wrong, tell us what you are seeing and we will rework it.
North Dakota development is organised around spacing units, typically 1,280-acre units running two sections. What matters to your value is which unit your acreage falls in, how many wells that unit already has, and how many the operator can still drill into the Bakken and Three Forks benches. A tract in a unit with three producing wells and room for five more is a different asset than one in a fully developed unit where the drilling is finished and the only direction left is decline.
Bakken wells decline steeply — a large share of total recovery arrives in the first two or three years. This makes recent royalty checks a poor guide to long-run value on new wells and a reasonable guide on old ones. An owner receiving large checks from a well completed last year is looking at a number that will fall substantially. An owner receiving modest checks from 2014-vintage wells is looking at something closer to a durable annuity.
North Dakota associated gas has historically been constrained by processing and takeaway capacity, and gas capture requirements affect how much of the gas stream actually reaches a sales point and generates royalty. Acreage connected to adequate gathering infrastructure produces more realised royalty per barrel of oil than acreage where the gas is flared or curtailed.
A meaningful share of North Dakota minerals sit under federal, state or Fort Berthold trust acreage, each with distinct royalty rates and administrative processes. Interests within the reservation boundary involve BIA administration and a different timeline. These positions are quotable, but the ownership category is a real input rather than a footnote.
North Dakota levies a 5% gross production tax plus a 5% oil extraction tax, for a combined effective rate near 10% on most oil production. Stripper-well and incentive provisions reduce the extraction component to 0% or 3% in defined cases. Natural gas is taxed on a per-Mcf basis rather than as a percentage, at a rate indexed to gas prices. Because valuation runs off net cash flow, this is the single largest structural drag on North Dakota mineral values relative to comparable acreage elsewhere. It does not make North Dakota minerals bad — Bakken well productivity is high enough to carry the tax — but it does mean a North Dakota royalty decimal is worth less than the same decimal on equally productive acreage in a lighter-tax state.
What that looks like on $1,000 of gross royalty
On $1,000 of gross oil royalty value, North Dakota takes roughly $100 in combined production and extraction tax. Ohio, by comparison, takes about $0.10 per barrel — on $1,000 of oil at $70, that is roughly $1.40. The two states are not remotely comparable on tax drag, and any valuation that ignores this is wrong by a wide margin.
Statute: NDCC ch. 57-51 (gross production tax), ch. 57-51.1 (oil extraction tax). Severance and production tax rates change with legislation and with well-level exemptions. Verify the current rate against the state agency before relying on it for a valuation.
North Dakota value is concentrated in the Bakken core. McKenzie, Williams, Mountrail and Dunn hold the most productive acreage and the most active development. Divide and Burke sit on the northern edge with materially weaker well results. Outside the Williston Basin fairway, North Dakota minerals have limited development prospects at current prices.
Non-producing North Dakota minerals inside the core fairway have real value, because operators continue infill drilling and undeveloped Three Forks benches remain across much of the core. Outside the fairway, non-producing acreage carries substantial uncertainty. Any non-producing North Dakota interest also needs a dormancy check before it can be valued — see below, because this is the state where that matters most.
North Dakota has the most aggressive dormant mineral act in the country. After twenty years of non-use — no production, no lease, no recorded statement of claim, no payment of taxes on the interest — the surface owner of the tract may publish a notice of lapse. The mineral owner then has sixty days from publication to file a statement of claim preserving the interest. If nothing is filed, the mineral interest reverts to the surface owner. This is why North Dakota mineral title work routinely involves a twenty-year non-use audit, and it is the reason an idle North Dakota interest needs checking before anyone can tell you what it is worth. If you hold a long-dormant North Dakota interest, filing a statement of claim is the step that protects it. If you are unsure whether a lapse notice has run, that is worth establishing before you do anything else — including selling.
It depends almost entirely on whether the acreage sits in the Bakken core and how much drilling is left in the spacing unit. A per-acre number quoted without reference to the unit, the well count and the remaining bench inventory is not describing your tract. Send the legal description and we can be specific.
Yes. Under NDCC ch. 38-18.1, twenty years of non-use exposes the interest to a lapse notice published by the surface owner, and you have sixty days from publication to file a statement of claim. This is a genuine risk that does not exist in Texas or Oklahoma, and it is the first thing to check on any idle North Dakota interest.
North Dakota stacks a 5% gross production tax and a 5% oil extraction tax, so most oil production carries a combined rate near 10%. Bakken wells are productive enough to support that, but it does reduce net royalty and therefore value compared with the same decimal on similar acreage in a lighter-tax state.
Usually not. Bakken wells decline steeply, with much of total recovery in the first two or three years. A large drop from an initial peak is normal well behaviour rather than a sign of a problem. It does mean that valuing off a recent check from a new well substantially overstates the long-run stream.
Send us the legal description and a recent check stub if you have one. We underwrite the tract and come back with a written offer in 48 hours. There is no cost and no obligation to accept it.