Selling mineral rights before a permitted well is drilled trades an uncertain future royalty for a fixed price agreed now, and the buyer takes on the drilling, production and price risk, if the tract participates in the well at all. Waiting replaces guesses with production records but keeps that risk with the owner.
Many owners first hear about their minerals the same way: a drilling permit is filed near their tract, and within weeks several purchase offers arrive in the mail. The usual advice is to hold on, because the royalties from a new well may add up to more than the offer. Sometimes that is right. Sometimes it is not. First, check whether the new well will pay your tract at all. Then this guide explains what is actually known at each stage between a permit and a producing well, so you can weigh the choice for your own situation.
The real question: a price agreed now or possible income later
An offer on undrilled minerals is a price for something that has not happened yet. If you hold, you keep the chance of royalty income from the new well, along with the uncertainty about when it starts, how much it produces and what oil and gas sell for when it does. If you sell, you trade that chance for a fixed price agreed now, and the buyer takes on the uncertainty. Neither choice is right for everyone. The answer depends on the well, and on you.
First: does the new well include your tract?
A permit near your land does not by itself mean the well will pay you. A well's royalties go to the tracts that participate in it: usually the tracts in its spacing, drilling or pooled unit, and, for some horizontal wells that cross more than one unit, tracts that share under an allocation or production-sharing arrangement. At the permit stage the unit may not be final. Pending spacing or pooling filings with your state regulator, and any pooling notice you receive, show what is proposed, and the operator can tell you whether your tract is expected to participate. A division order comes later, near first production, and states the share the operator intends to pay; check it against your deed, lease and unit records, because it can contain errors. If your tract does not participate, waiting for that well does not preserve any royalty from it. How drilling units and spacing affect your royalties explains how the share is set.
What each drilling stage tells you
Picture one tract as it moves from a permit to a producing well. At each step, something that was uncertain becomes known, and what an offer is pricing changes with it. The stages below are general. Your state regulator's records show where a particular well stands, but they can lag behind it: first production can take months to appear in state records, so confirm the current stage with the operator.
| Stage | What is known | What is still uncertain |
|---|---|---|
| Permitted | An operator has filed to drill a well at a stated location and target formation. | Whether and when the well is drilled. A permit is not a commitment to drill, and permits can expire unused. |
| Drilled, not yet completed | The wellbore exists, so the operator has spent money on it. | When it will be completed and turned to sales, and how much it will produce. |
| First production | The well is producing and early volumes start to appear in public production records. | How fast production will decline from its early rate, and what prices will be over the well's life. |
| Producing with history | Months of production show how the well is performing. Where records report each well separately, that is the well's own decline; some states, Texas among them for oil, report production by lease, so the figures combine every well on it. Royalty statements show what reaches you. | Future prices, and whether more wells are drilled on or near the tract. |
An offer before drilling is priced on what might happen. An offer after a year of production is priced mostly on what has happened. Waiting replaces guesses with records, but it does not remove risk, and it does not by itself make an offer go up.
A worked example, without the numbers
Take a family that inherited a small mineral interest in a county where a new horizontal well has just been permitted in a unit that includes their tract. Over the following weeks, a few purchase letters arrive. Here is how the decision looks from each side.
If they wait for the well. They keep the full upside if the well is drilled soon and produces well. They also carry every risk: the well may be delayed or never drilled, for most oil and shale gas wells, early production is the highest the well will ever produce (coalbed methane wells are an exception and often rise at first as water is pumped off), prices can move against them, and if the interest is split among several heirs, each share of a royalty check can be small. Until the well is producing, they receive nothing from it.
If they sell now. They agree a fixed price for the interest, and the buyer carries the drilling, production and price risk. They give up any income the well would have paid, and any later wells on the tract. If the well turns out better than expected, the buyer keeps that difference; if it is delayed or disappoints, the buyer bears that too.
If they do a bit of both. They sell part of the interest now and keep the rest, so part of their interest has an agreed price and the rest still shares in the well. Or they wait for first production, read the early records and decide then. Each middle path keeps some upside and some risk.
The example has no prices in it on purpose. How much any of these choices is worth depends on the specific tract, the lease, the operator, the formation and prices at the time. A rule of thumb from another county or another well will not answer it.
Questions to weigh
- How soon, if at all, do you need the money, and for what?
- How long are you prepared to wait for royalties that may start late, or not at all?
- Has the well been drilled, or is it only permitted?
- How many people share the interest, and would they rather split a royalty stream or a sale price?
- How much of what you own depends on this one well or tract?
- Do you want to keep up with division orders, royalty statements and tax paperwork for years?
Owners answer these differently, and there is no answer that fits everyone. This guide does not recommend holding or selling. Tax treatment differs between holding royalties and selling, and it depends on your situation; a CPA can explain how each choice would affect you, and a financial advisor can help you weigh it.
Middle paths: selling part, or selling later
Selling is not all-or-nothing. You can sell a fraction of your interest and keep the rest, as selling part of your mineral rights explains. You can also wait until the well has produced for a while and sell then, when an offer can be priced on actual production records. Waiting has its own cost: the time until the well produces, and the chance that it is never drilled. The cost of holding mineral rights covers what owners pay while they wait.
How to check where a well stands
Before you decide, find out which stage the well is actually in. Permits and completion reports are public and are filed with your state's oil and gas regulator. Production records are public too, but in some states they are kept by the tax or revenue agency rather than the regulator. Those records can trail what is happening on the ground, so ask the operator too. Tracking operator activity near you shows where to look. If you received a pooling notice instead of, or as well as, a purchase offer, that has its own deadlines; see what to do with a forced pooling notice.
How to get an offer you can compare
If you are considering a sale, ask each buyer for the offer in writing, stated for your interest: the net mineral acres or decimal interest covered, the tracts and depths, the total price, who pays closing costs and what the offer is subject to. Ask which stage of drilling the offer assumes. How to judge a mineral rights offer and why you are getting offers cover the rest.
Buckhead takes a no-pressure approach — we do not pressure you to sign. If you would like a figure for your own interest, you can request a Free Written Offer. This article is general education, not legal, tax or financial advice; an attorney, CPA or financial advisor can advise on your situation.
Key Takeaways
- A well near your land pays only the tracts that participate in it; confirm with the operator that your tract is included before weighing its royalties.
- A permit is not a commitment to drill; a well can be delayed or never drilled.
- Each stage from permit to production turns some uncertainty into public records.
- Selling now moves drilling, production and price risk to the buyer; holding keeps it with you.
- Your need for cash, how long you can wait, how many people share the interest and how concentrated you are in one tract all bear on the choice.
- Selling part of the interest, or selling after first production, are middle paths.
- Ask for written offers stated for your interest, and ask which drilling stage the offer assumes.
Frequently Asked Questions
Should I sell my mineral rights before the well is drilled?
It depends on your situation. Selling before drilling fixes the price now and moves the drilling, production and price risk to the buyer. Holding keeps the chance of royalty income and the risk that the well is delayed, never drilled or produces less than hoped.
Why am I getting offers right after a drilling permit was filed?
Drilling permits are public records, and buyers read them. A new permit suggests an operator may drill in the area, which is often why owners nearby hear from buyers at the same time.
Will I get royalties from a well drilled near my land?
Only if your tract participates in the well: usually because it is in the well's spacing, drilling or pooled unit, or, for some horizontal wells, under an allocation or production-sharing arrangement. Early on, pending spacing or pooling filings and the operator can tell you what is proposed; a division order later states the share the operator intends to pay, which you can check against your deed, lease and unit records.
Will my minerals be worth more after the well starts producing?
Not necessarily. Once a well produces, an offer can be based on actual production rather than expectations. If the well performs well, that can support the offer; if it disappoints or prices fall, it can lower it. Waiting settles whether the well is drilled and how it starts out; it does not settle how fast it declines, what prices do or whether more wells follow.
Can I sell part of my mineral rights and wait on the rest?
Yes. Mineral ownership is divisible, so you can sell a fraction of your interest and keep the remainder. The deed sets what is conveyed and what you keep, so have an attorney prepare or review it before you sign.
How do I find out whether the well near me has been drilled?
Check your state oil and gas regulator's public records for the permit and the drilling and completion reports, and look for production data with the regulator or, in some states, the tax or revenue agency. Ask the operator too, because state records can trail the well by months. A division order usually means payment is being set up; your first royalty statement or check stub shows when payments have actually started.
Disclaimer: Buckhead Energy is not a tax, legal, or investment advisor, and nothing in this article should be construed as tax, legal, or investment advice. This information is general in nature and provided solely for your convenience and education. Every owner's situation is different — always consult a qualified CPA, tax professional, attorney, or financial advisor before making any decision regarding your mineral rights, taxes, or finances.
