Frequently Asked Questions

Don't sign anything yet, and don't feel rushed. Ask for the full offer in writing, including the complete contract and not just a summary letter. Write down who contacted you, the company they represent, and what they promised verbally. Then take time to review the terms or have them reviewed. Legitimate offers rarely disappear in a few days, even when the person says they will.

Sometimes, but deadlines are one of the most common pressure tactics. A short deadline keeps you from comparing offers, talking with neighbors, or getting advice. It's reasonable to say you need time to review the contract. If the deadline is real and tied to something specific, like a drilling permit or project filing, ask them to explain it in writing.

Almost always. Bonus amounts, royalty or rent rates, lease length, payment timing, surface protections, and many other terms are routinely negotiated. "This is our standard form" doesn't mean it can't be changed. It means it was written to favor the company.

Get it added to the contract in writing. Most agreements include a clause saying the written document is the entire agreement. That means verbal promises about fences, roads, water, or payments may be impossible to enforce later.

Often, yes. Neighbors may have received offers from the same company, and comparing terms is one of the best ways to learn what's realistic. Some agreements include confidentiality clauses, so check what you've already signed before you share details.

In Texas and Oklahoma, the minerals and the surface can be owned separately. Whoever owns the minerals can lease them for oil and gas development and receives the bonus and royalties. The surface owner owns the land itself but may have no say in, and receive no royalties from, the minerals underneath.

Read more: Mineral Rights vs. Surface Rights, Explained

A lease bonus is a one-time payment, usually quoted per net mineral acre, that the company pays when you sign an oil and gas lease. It's separate from royalties, which you receive only if and when there's production. Bonus amounts vary widely by county, formation, and drilling activity, so comparing recent offers in your area matters.

Older leases often used 1/8 (12.5%). In active areas today, landowners commonly negotiate 3/16 (18.75%), 1/5 (20%), or 1/4 (25%). What's realistic depends on location and how much the company wants your acreage. The royalty rate is usually worth more over time than the bonus.

Post-production costs are expenses for things like gathering, compressing, processing, and transporting oil and gas after it leaves the well. Depending on how your lease is written, some of these costs may be deducted from your royalty checks, sometimes heavily. A "no deductions" or "cost-free royalty" clause can make a big difference in what you're actually paid.

Read more: Bonus vs. Royalty: The Two Numbers That Actually Matter

A division order is a document from the operator or purchaser confirming your decimal interest in a well so they can pay you. It's meant to confirm ownership, not to change your lease. Check that the decimal interest is correct before you sign. Our free royalty calculator can help you check the math.

Your decimal interest is the share of a well's production you're entitled to, expressed as a decimal (for example, 0.00390625). It's generally calculated from your net mineral acres, the size of the drilling unit, and your royalty rate. If your decimal looks low, it's worth asking how it was calculated.

In Oklahoma, if you don't lease, an operator can ask the Oklahoma Corporation Commission to "pool" your minerals into a drilling unit. You then typically choose from options set in the pooling order, such as a cash bonus with a royalty, or participating in the well's costs. Elections have strict deadlines, and if you miss one, an option is usually chosen for you. Texas also has a pooling statute, but it's used far less often. In Texas, pooling usually happens through lease terms.

A Pugh clause releases the parts of your leased acreage, or the deeper depths, that aren't included in a producing unit once the primary term ends. Without one, a single well on part of your land can hold your entire lease indefinitely.

Most leases have a "primary term," often three to five years, plus an option to extend. After that, the lease continues "as long as oil or gas is produced," which can mean decades. Pay close attention to extension options, shut-in royalty clauses, and anything else that keeps the lease alive without real production.

Both Texas and Oklahoma have laws setting deadlines for royalty payments and requiring interest on late payments in many situations. Start by requesting a written explanation of how your payment was calculated. Keep copies of check stubs, your division order, and your lease.

Generally, yes. In both states, the mineral owner (and the company leasing the minerals) has the right to reasonably use the surface to develop the minerals. That's why surface owners often feel they have little leverage. You still have rights, and how much depends a lot on which state you're in.

In Oklahoma, yes. The Oklahoma Surface Damages Act requires the operator to give notice and negotiate surface damages before drilling. If you can't agree, the law provides a court process with appraisers to set the amount. Texas has no general surface damages statute, so compensation usually depends on negotiating a surface use agreement.

Read more: Surface Damages in Oklahoma vs. Texas: Same Rig, Very Different Rights

Common terms include where the well pads, roads, pipelines, and tank batteries can go; payment for damages; fencing and gates; livestock protection; dust and erosion control; water use; restoring the land after operations; and who's responsible for cleanup. Get every promise in writing.

It's a Texas rule that can require a mineral operator to use an alternative method of development if its planned use would substantially interfere with an existing surface use, such as irrigation, and a reasonable alternative is available. It applies only in limited situations, but it can matter.

Yes. A pipeline easement gives a company a long-term or permanent right to cross your land. Key terms include the width of the easement, whether it allows more than one pipeline, what can be transported, depth of burial, restoration, and payment. Some pipeline companies have eminent domain authority, which changes how negotiations work. Ask directly whether they claim it.

Start with the deceased person's records: old royalty check stubs, tax statements, division orders, deeds, and the will or probate file. County clerk land records list mineral deeds and leases. In Oklahoma, Corporation Commission records can show activity on specific land. State unclaimed property sites in Texas and Oklahoma may also hold unpaid royalties in the family's name.

Usually you need a document that legally transfers ownership, such as a probated will, a court order determining heirs, or an affidavit of heirship, recorded in the county where the minerals are located. Which route works depends on the state, the county, the value of the minerals, and whether a will exists. Operators often won't release payments until title is cleared up.

Operators commonly put payments "in suspense" until they receive proof of who the new owner is. The money is usually still there. Contact the operator's owner relations department, ask what documents they need, and ask whether interest is owed on the held funds.

That's a personal decision, but don't decide under pressure. Unsolicited offers to buy minerals often arrive soon after a death, and they're sometimes well below value. Find out what the minerals are producing and whether new drilling is nearby, and compare more than one offer before you sign.

Each heir typically owns an undivided share. That means each of you can lease or sell your own share, but nobody owns a specific piece of the land. Families often coordinate so everyone is negotiating from the same information.

AI and cloud computing have created huge demand for data centers, which need large tracts of land near power, water, and fiber. Texas and Oklahoma have all three, plus available land, so developers and land agents are actively looking for sites, often before announcing anything publicly.

An option gives the developer the exclusive right to buy or lease your land during a set period, often a year or more with extensions, in exchange for option payments. During the option period you usually can't sell or lease the land to anyone else. The developer can walk away, but you're locked in.

Read more: Exclusivity Agreements: What You Give Up During the Option Period

It depends on your goals. A sale gives you a lump sum and ends your ownership. A long-term ground lease can provide decades of income while you keep the land, but it ties up the property for a very long time. The tax consequences can also differ significantly. Weigh both before committing.

Developers often work for large tech companies that keep sites confidential until zoning and financing are in place. You may be asked to sign a nondisclosure agreement. That's common, but read what it actually restricts, including whether it prevents you from getting advice or talking with neighbors.

Not necessarily. The option fee is the price of holding your land off the market, not the purchase price. Look at the final purchase price or rent, how and when it's paid, what happens if the deal closes on only part of your land, and whether payments increase over time.

Data centers can bring new transmission lines, substations, roads, water use, noise, and lighting. If you're selling part of your property, think about how the project affects the land you keep, including access, drainage, and future use.

Data center developers themselves generally don't have eminent domain power. But utilities building the power lines and substations that serve a data center may. Knowing who is asking, and in what capacity, matters a lot.

A solar developer typically signs an option or lease covering an initial development period, often with modest annual payments. If the project moves forward, construction and operating periods follow, with rent paid per acre each year, often for 20 to 40 years or longer counting extensions.

Read more: How Solar Lease Payments Actually Work

Rents vary widely by location, how close the land is to transmission lines, and market competition. Compare the offer against other offers in your area. Also look at annual rent escalators, which raise the payment over time, and whether you're paid on all the leased acreage or only the acres actually used.

That's the decommissioning question, and it's one of the most important parts of the lease. The agreement should require the company to remove all equipment, including below-ground components, and restore the land. It should also require financial security, such as a bond, so the cleanup happens even if the company is gone. Both Texas and Oklahoma have adopted decommissioning requirements for certain renewable projects. Make sure your lease meets or exceeds them.

Sometimes. Some leases allow grazing (often sheep) under or around panels, or let you keep farming the parts of the land not being used. If that matters to you, negotiate it into the lease. Don't assume it.

Converting land from agricultural use can affect agricultural valuation or exemptions, and in some cases can trigger rollback taxes. The lease should say who pays any tax increase caused by the project. Ask your county assessor or tax professional how it would apply to your land.

Most solar leases let the developer assign the lease to another company, and projects often change hands before they're built. Consider requiring notice of any assignment and making sure the new company takes on all obligations, including decommissioning.