To get an oil company to drill on your land, you need to confirm you own the mineral rights beneath it, show that your property sits in a geologically promising area, and approach operators already active nearby with clean documentation. That is the short version of how to get oil companies to drill on your land. Everything else, from bonus payments to post-production deductions, follows once you can prove ownership and point to a reason a company would spend millions putting a well down.
Confirm You Own the Mineral Rights
Surface ownership and mineral ownership are separate legal interests in the United States. You can own the house, the barn, and the pasture while someone else owns the oil and gas underneath. This split happens when a previous owner sells or reserves the minerals in a deed, and it is common in states with a long history of oil and gas production.
The mineral owner, not the surface owner, decides whether to lease for drilling. If you bought your property without checking whether the minerals came with it, you may not have authority to negotiate a lease at all. Pull your deed and look for any language reserving mineral rights to a prior owner. If the deed is ambiguous or points back to older conveyances, hire a real estate attorney to run a title search through the county recorder’s chain of title. The search will show whether the minerals were severed at some point.
If the minerals belong to someone else, your options narrow to buying them back, which is a separate negotiation. If you own them free and clear, you control everything that follows.
Figure Out Whether the Geology Supports a Well
Oil companies do not drill on hunches. They rely on geological data to estimate what is below the surface before spending money on a well, and much of that data is publicly available.
Start with your state’s geological survey or oil and gas commission. Most maintain searchable databases of well logs, production records, and permits showing where companies have drilled, what they found, and how those wells have produced. Proximity to existing production is the strongest signal. Land near active wells or inside an established field is far more attractive to operators because the geological risk is lower.
For a closer look, hire a petroleum geologist or a professional landman. A geologist can interpret seismic data and well logs to estimate whether your tract sits over a productive formation. A landman researches mineral ownership and evaluates lease opportunities. Either can tell you honestly whether your land is worth marketing, or whether the geology simply is not there. That answer saves you time and credibility before you start calling companies.
Approach the Right Operators
Once you have confirmed ownership and have reason to believe the geology is favorable, make contact. State oil and gas commission websites list permit holders and active operators by county. Industry directories can help you find companies focused on your region’s formations.
Contact the company’s land department directly, or reach out to a landman working on its behalf. Landmen are the intermediaries who research titles, negotiate leases, and manage paperwork between companies and mineral owners. Keep the pitch straightforward: property location, acreage, and confirmation that you hold clear mineral title. Operators receive plenty of inbound pitches, and the ones with clean documentation and real geological context get taken seriously.
Do not stop at one company. If several operators are active nearby, reach out to more than one. Competition gives you leverage on lease terms. And if no one bites, that answer is useful too: it usually means the geology, economics, or pipeline infrastructure in your area does not currently support new drilling.
Negotiate the Lease Carefully
The oil and gas lease defines what the company can do on your land, how long they can do it, and what you get paid. Standard company forms almost always favor the operator. Negotiation is where you protect yourself, and every substantive term deserves attention.
Primary and Secondary Terms
Every lease has a primary term, typically three to five years, during which the company holds the exclusive right to explore and drill. If no well is started and no payments extend the lease, it expires at the end of that period and your minerals are free again.
Once production begins, the lease enters its secondary term and stays alive as long as the well produces in paying quantities. That phrase has legal teeth: it generally means the well must earn enough to exceed operating costs, giving a reasonable operator incentive to keep it running. A trickling well can still hold your lease for decades if the operator argues it is economically viable, which is why the language around what counts as production matters.
Bonus and Royalty
The bonus payment is your upfront money, a one-time per-acre amount paid when you sign. You keep it whether or not a well is ever drilled. Amounts vary widely depending on location, geological promise, and competition among operators.
The royalty is your ongoing share of production revenue. Royalty rates in private leases typically range from 12.5% to 25% of the value of oil or gas produced. The old standard was one-eighth (12.5%), but in active plays with competing operators, landowners regularly negotiate higher percentages. Royalties are generally free of drilling and production costs. What happens after the product leaves the wellhead is where things get complicated.
Post-Production Deductions
This is where most landowners get surprised. Your lease might promise a 20% royalty, but your check can come in significantly smaller after the company subtracts post-production costs. These usually include transportation, gathering, compression, processing, and dehydration.
Whether the company can deduct any of that depends on your lease language. Some leases allow the operator to subtract a proportional share of post-production expenses. Others prohibit deductions and require payment based on the gross sales price. The difference can amount to thousands of dollars a month on a producing well. If your lease is silent or ambiguous on the point, assume the company will read that ambiguity its own way. Negotiate for royalty calculated on gross proceeds at the point of sale, free of deductions.
Protective Clauses
Beyond the headline financial terms, several clauses shape your long-term position:
- A Pugh clause prevents the operator from holding your entire tract based on production from just one small portion of it. Without this clause, a single well on one corner can tie up hundreds of acres indefinitely. A Pugh clause releases the non-producing acreage at the end of the primary term.
- Delay rental provisions require annual payments to keep the lease alive during the primary term if drilling has not started. Without them, the company can sit on your lease for years without paying you or doing any work.
- Shut-in royalty payments cover periods when a well is capable of producing but is not connected to a pipeline or actively marketed. Set a time limit so the company cannot hold your lease indefinitely on a capped well.
- Surface use and damages clauses specify where the company can place well pads, roads, and pipelines, and what you receive for surface disturbance. State surface damage laws often require compensation for crop loss, lost land value, and disruption to water supplies, and your lease can add protections beyond those statutory minimums.
- Pooling or unitization clauses let the operator combine your tract with neighboring parcels into a single drilling unit, with your royalty based on your proportional acreage. Pooling can help when your tract alone is too small for a well, but watch for overly broad pooling authority that lets the company build enormous units and dilute your share.
Have an oil and gas attorney review any lease before you sign. A few hundred dollars in legal fees can protect a revenue stream worth many times that over the life of a well.
Forced Pooling If You Refuse to Sign
Roughly three dozen states have some form of compulsory pooling law. These statutes let an operator include your minerals in a drilling unit even if you refuse to sign a lease, provided enough other mineral owners in the proposed unit have agreed. The purpose is to prevent one holdout from blocking development of a shared underground reservoir.
If you are pooled involuntarily, you typically have two options: participate as a working interest owner by paying your proportional share of drilling costs upfront, or be carried by the operator and receive a reduced royalty, often the statutory minimum of one-eighth, free of drilling costs. You do not receive a bonus, because no lease is signed. The pooling order generally applies only to the specific well and unit in question, not your whole property. This is one reason engaging with operators usually produces better financial terms than refusing contact.
Taxes on Lease and Royalty Income
Every dollar you receive from an oil and gas lease is taxable, and the structure matters. Lease bonus payments and royalty income are both reported as rental income on Schedule E of your federal return. Neither is subject to self-employment tax for mineral owners who hold a royalty interest rather than a working interest. Both are subject to the 3.8% net investment income tax if your modified adjusted gross income exceeds the applicable threshold.1IRS. Questions and Answers on the Net Investment Income Tax
The biggest tax benefit for royalty owners is the percentage depletion allowance, which recognizes that the resource beneath your land is being used up as it is extracted. Independent producers and royalty owners can deduct 15% of their gross royalty income as depletion, up to a limit of 1,000 barrels of oil per day or an equivalent amount of natural gas.2Office of the Law Revision Counsel. 26 USC 613A – Limitations on Percentage Depletion in Case of Oil and Gas Wells Depletion is reported on Schedule E alongside your royalty income. You can also deduct related expenses like property taxes on the mineral interest, legal fees for lease negotiation, and tax preparation costs attributable to the royalty income.
Work with a tax professional who understands oil and gas income. The interaction between depletion, the net investment income tax, and your overall tax picture is complex enough that general tax software often misses available deductions.
After Drilling Begins
Once drilling starts, expect heavy equipment, well pad construction, pipeline installation, and truck traffic. Even a single conventional well changes the character of your property for months during drilling and completion.
After production starts, monthly royalty statements should detail the volume produced, the price received, and any deductions applied. Review them. Operators sometimes apply deductions the lease does not authorize, miscalculate volumes, or fail to account for production from all wells on the tract. Ask for documentation when numbers look wrong. Your lease should include an audit right letting you inspect production and sales records. Negotiate for one before signing if the draft omits it. A professional production audit can cost tens of thousands of dollars, so most landowners only pursue one when payment discrepancies suggest a systematic problem. Contact your state’s oil and gas regulatory agency if you believe an operator is violating well spacing rules, environmental requirements, or permit conditions.
When the Well Stops Producing
Every well eventually stops producing. When that happens, the operator is responsible for plugging the well, removing surface equipment, and restoring the land. Most states require operators to post a bond or other financial assurance before drilling begins, specifically to guarantee that plugging and reclamation happen even if the company goes bankrupt.
Despite these requirements, thousands of wells across the country have been abandoned by operators who disappeared or went broke, leaving landowners with unplugged wells and contaminated soil. Federal law now provides funding for states to plug and remediate orphaned wells on both state-owned and private land, including restoring native habitat degraded by abandoned well sites and infrastructure.3Office of the Law Revision Counsel. 42 USC 15907 – Orphaned Well Site Plugging, Remediation, and Restoration The process is slow and the backlog is large.
Your best protection is lease language that clearly assigns restoration responsibility to the operator, sets a deadline for removal of equipment after production ceases, and requires the surface to be returned to its original condition. If the company you are leasing with is small or thinly capitalized, pay close attention to its financial health. The most generous royalty rate in the world does not help if the operator folds and leaves you with an environmental mess.