Mineral rights in Texas work on a simple but consequential principle: the ground under your feet and the oil, gas, or other minerals beneath it can belong to two different people. Nearly all mineral rights in the state are privately held, and once minerals have been separated from the surface, that split is permanent. Understanding how mineral rights work in Texas means understanding what happens when the two estates are severed, who gets to decide what happens on the land, and what a mineral owner actually holds when they sign a lease.
Surface and Mineral Estates Are Separate
Property ownership in Texas usually starts as a single estate covering the surface and everything below it. A landowner can permanently split that estate through a process lawyers call severance: selling the surface but keeping the minerals, or selling the minerals while keeping the surface. The split is recorded in a deed filed with the county clerk, and Texas law requires that any instrument conveying real property be signed and acknowledged before it can be recorded.1State of Texas. Texas Property Code Chapter 12 – Recording of Instruments From that point forward, the surface and the minerals are two separate pieces of real property. Each can be sold, leased, inherited, or taxed on its own.
Here’s what catches buyers off guard. Severance could have happened generations ago, buried in a deed from the 1920s that nobody in the current chain of ownership ever read carefully. One person might raise cattle on the surface today while someone completely unrelated owns the oil a mile below, and the arrangement can last indefinitely unless a single buyer eventually acquires both interests.
The Mineral Estate Comes First
Under Texas law, the mineral estate is the dominant estate. Whoever owns the minerals, or any company they have leased to, has the right to use the surface for exploration and production without the surface owner’s permission. That includes building roads, drilling wells, running pipelines, and conducting seismic testing. The lessee does not have to ask first and does not have to restore the surface or pay for non-negligent damage.2Railroad Commission of Texas. Oil and Gas Exploration and Surface Ownership
The law does impose limits. If operations are negligent, unreasonable, or excessive, the surface owner can sue for damages.2Railroad Commission of Texas. Oil and Gas Exploration and Surface Ownership The Texas Supreme Court also established the accommodation doctrine in Getty Oil Co. v. Jones.3Justia. Getty Oil Co. v. Jones, 1971 Under that rule, if a mineral operator’s activities would destroy an existing surface use and the operator has a reasonable alternative method available, the operator must use the alternative. The classic example is a farmer with a pivot irrigation system: the driller cannot place a well where it would wipe out the irrigation if moving the well a few hundred feet would work just as well.
The doctrine is narrower than many surface owners assume. It applies only when the surface owner can prove an existing use would be substantially impaired and a feasible alternative exists for the mineral operator. It does not give surface owners a general veto over where wells go.
Protecting the Surface With a Written Agreement
Because the law tilts heavily toward the mineral estate, surface owners who want real protection should try to negotiate a surface use agreement before drilling begins. The Railroad Commission notes that surface owners can attempt to negotiate agreements restricting how operators use the land or setting compensation for surface damage.2Railroad Commission of Texas. Oil and Gas Exploration and Surface Ownership No law requires the mineral owner or lessee to agree. Many operators will accept reasonable terms to avoid litigation, so if you own the surface and someone else owns the minerals, getting an agreement in writing before the first truck shows up is the single most important step you can take.
What a Mineral Interest Actually Includes
A severed mineral interest in Texas is really a bundle of five separate rights, and each one can be owned by a different person:
- Executive right: The power to negotiate and sign oil and gas leases. This is the most consequential right because the executive’s decisions bind all other interest holders in the tract.
- Bonus: The upfront per-acre payment a lessee makes when a lease is signed.
- Delay rentals: Annual payments to hold a lease during the primary term if drilling has not started. These compensate the mineral owner for the operator sitting on the acreage.
- Royalty: A cost-free share of production revenue, expressed as a fraction. The traditional standard was one-eighth, but one-quarter and other fractions are now common.
- Ingress and egress: The right to physically enter the property to explore for and produce minerals.
These rights can be carved up and transferred independently, which is how mineral ownership in Texas gets complicated fast. You might own a royalty interest with no say in who leases the land, or hold the executive right over minerals in which you have no financial stake. When someone holds the executive right over interests they do not own, Texas courts impose a duty of utmost good faith and fair dealing. The executive cannot negotiate a lease that enriches themselves at the expense of royalty owners, though courts have acknowledged the executive is not required to wholly subordinate their own interests either.
How Texas Oil and Gas Leases Are Structured
Most Texas oil and gas leases follow a two-phase structure controlled by the habendum clause. The primary term, commonly three to five years, gives the operator an exclusive right to explore and develop. During this period, the operator typically pays delay rentals if it has not started drilling.
The lease continues beyond the primary term only if there is production in paying quantities. Texas courts have interpreted this to mean the well must generate enough revenue to cover current operating and marketing costs, not that the operator needs to recoup its entire drilling investment. A well that has never paid back its original drilling costs but still turns a small operating profit qualifies to hold the lease.
If production stops and no other lease provision keeps the agreement alive, the lease terminates automatically. This is one of the most litigated areas of Texas mineral law. Small details in the habendum clause can determine whether a mineral owner gets their rights back or stays locked into an underperforming lease for years. Before signing a new lease, pay close attention to shut-in royalty clauses, cessation-of-production provisions, and pooling language, all of which can extend the lease well beyond the primary term without meaningful production.
Pooling in Texas
Pooling combines multiple tracts of land into a single production unit so one well can draw from the entire area. This matters especially with modern horizontal drilling, which often extends across several properties. Under a pooling arrangement, mineral owners share royalties proportionally based on the acreage they contribute.
Texas generally relies on voluntary pooling, where all mineral owners agree to combine their tracts. Unlike Oklahoma, North Dakota, and many other oil-producing states, Texas does not have a broad forced-pooling statute that lets operators compel unwilling mineral owners into a unit. That is a meaningful protection for Texas mineral owners who do not want to be swept into a deal on someone else’s terms. The flip side is that small-tract owners who refuse to participate may miss out on development entirely if an operator cannot justify drilling on their parcel alone. Lease pooling clauses, which give the operator the right to pool your minerals with adjacent tracts, deserve careful scrutiny before you sign.
The Rule of Capture and Drainage
Texas follows the rule of capture: you own whatever oil or gas you produce from a well on your property, even if some of it migrated from under your neighbor’s land through natural underground pressure changes. The legal system treats subsurface oil and gas as fugitive resources that belong to whoever captures them through lawful production.
The rule has clear boundaries. The Texas Supreme Court held in Elliff v. Texon Drilling that the rule of capture does not protect negligent or wasteful operations. If an operator’s negligence destroys oil and gas that neighboring owners could have recovered, those neighbors can sue for their losses. Slant-hole drilling, where a wellbore is intentionally angled to tap into a reservoir beneath someone else’s property, is flatly illegal, and an operator caught bottoming a well under another owner’s lease faces the same legal consequences as a physical trespasser.4Justia. Harrington v. Railroad Commission, 1964
The practical defense against drainage is straightforward: drill your own well. Courts have consistently held that allowing every landowner a fair opportunity to produce their share is the foundation of the state’s regulatory structure.
Taxes on Mineral Production
Two layers of tax hit mineral production in Texas. The first is the severance tax, collected by the state when oil or gas is extracted. For oil, the tax rate is 4.6% of market value, with enhanced recovery projects that qualify under the statute paying a reduced rate of 2.3%.5State of Texas. Texas Tax Code 202-052 – Rate of Tax For natural gas, the rate is 7.5% of the market value of gas produced and saved.6State of Texas. Texas Tax Code Chapter 201 – Gas Production Tax Operators also pay a small oil-field cleanup regulatory fee on natural gas production. These taxes are typically withheld from the royalty check before it reaches the mineral owner, so you will see the deduction on your revenue statement.
The second layer is property tax. Producing mineral interests are classified as real property and assessed by the local county appraisal district, typically using a discounted cash flow method that estimates the present value of future production revenue. Your property tax bill on a mineral interest fluctuates with commodity prices and production decline rates, and you should expect an annual appraisal notice.
What the Railroad Commission Does
The Railroad Commission of Texas, which has not regulated railroads in decades, is the primary state agency overseeing oil and gas operations. Under the Texas Natural Resources Code, the commission sets well spacing rules, issues drilling permits, and establishes production limits to prevent waste.7State of Texas. Texas Natural Resources Code Chapter 85 – Conservation of Oil and Gas It also enforces well plugging requirements. A well that goes more than 12 months without reported production or other permitted activity is classified as a delinquent inactive well, and the commission can order it plugged.8Justia. Texas Natural Resources Code Chapter 89 – Abandoned Wells
One important limitation. The Railroad Commission does not settle ownership disputes or interpret private lease terms. If you disagree with a neighbor over who owns the minerals, or you think your lessee breached the lease, those disputes go through the Texas court system. The commission’s jurisdiction is limited to the technical and conservation aspects of drilling and production.
Finding Out Who Owns the Minerals
Figuring out who actually owns the minerals under a piece of Texas land is one of the hardest practical problems in the state’s property system. Because severance can happen at any point in the chain of title, sometimes a century ago, you need to trace every deed, reservation, and conveyance back through the county clerk’s records. This process is complicated and time-consuming even for experienced oil and gas attorneys. A single missed reservation in a 1930s deed can mean you do not own what you think you own.
Most buyers of rural Texas land should budget for a professional title search before assuming they hold any mineral rights. The standard approach involves a landman or title attorney sorting through deed records to identify every instance where minerals were reserved or severed. If mineral development is imminent, the operator will typically commission its own title opinion, but that opinion protects the operator, not you.
Texas does not have a dormant mineral act. Unlike some states that allow surface owners to reclaim severed mineral rights after a long period of inactivity, Texas offers no such mechanism. Once minerals are severed from the surface, they stay severed indefinitely, even if the mineral owner does nothing with them for generations. If you are buying Texas land and the seller cannot clearly demonstrate mineral ownership, assume the minerals were severed and price accordingly.