It’s the first question every owner asks, and the one most buyers answer with a shrug or a sales pitch. Here’s the truthful version: there is no posted price for mineral rights — but there is a logic to how they’re valued, and once you understand it, you can read any offer (including ours) with clear eyes.
The three buckets your minerals fall into
Before anything else, a buyer sorts your interest into one of three buckets. Each is valued completely differently.
- Producing. Your acreage is in a drilled unit and you receive royalty checks. This is the most valuable and most precisely priceable bucket — the wells have a track record.
- Leased, not drilled. You signed a lease, but no well yet. You’re holding a probability: the value depends on how likely, and how soon, drilling is.
- Open (unleased). No lease, no wells. Value rides almost entirely on location — core-county open acreage still draws real money; fringe acreage is speculative.
What actually moves the number
1. Location — county, township, section
The Utica is not one market. Dry-gas core counties like Belmont, Monroe, and Jefferson price off proven, prolific gas production. Liquids counties like Harrison and Guernsey add natural-gas-liquids revenue to the math. Fringe counties price on possibility. Within a county, one township — even one section — can be worth multiples of its neighbor.
2. The wells around you
For producing and leased acreage, nearby well performance is the backbone of any honest valuation. Production volumes are public record in Ohio — a serious buyer pulls them, models the decline curves, and projects what your acreage should earn. If a buyer can’t show you this work, they didn’t do it.
3. Your lease’s fine print
Two neighbors with identical acreage can hold wildly different value because one signed a 20% gross royalty and the other a 12.5% royalty with post-production deductions. The royalty percentage, deduction language, and unitization terms in your lease directly scale what your minerals earn — and therefore what they’re worth.
4. Commodity prices and the forward curve
Buyers don’t price on today’s headline gas price; they price on the futures market — what buyers of gas and oil are contractually paying for delivery years out. When the strip is strong, mineral offers strengthen with it. This is why offers genuinely change month to month.
The rules of thumb — and their limits
You’ll hear that producing minerals are worth “so many times your monthly check.” There’s truth in it: producing interests commonly trade somewhere around 3 to 7 years’ worth of current royalty income, sometimes beyond. But the multiple swings on everything above — a new well’s steep early decline argues for a lower multiple; undrilled acreage in the same unit argues for a higher one. A rule of thumb is a starting point for questions, not an answer.
If a number can’t be explained, it shouldn’t be trusted. Ours comes with the explanation attached.
Why two offers for the same land differ by six figures
Because buyers aren’t all buying for the same reason. A flipper needs to buy low enough to resell at a markup — their offer has a middleman’s margin carved out of your value. A fund with a deadline prices in their exit. A long-term holder like a family office can pay closer to full value because there’s no resale planned. Asking who you’re really selling to is the most profitable question in this whole process.
How to get a real number
- Gather what you have: royalty statements, your lease, the deed, parcel numbers. (Missing pieces are fine — we reconstruct them from courthouse records at no cost.)
- Get a written evaluation that shows the reasoning, not just a figure.
- Compare offers on identical terms: price after costs, closing timeline, and who pays for title work. (With us: we pay everything.)
- Take it all to your attorney. Any buyer who discourages that just answered your vetting question for you.
Our evaluation is free, parcel-specific, and yours to keep whatever you decide — request one here or use the short form on this page.