Understanding Mineral Interests: The Complete Guide for Buyers

By Richard Partin, Managing Member, Texas State Royalties LLC Fort Worth, Texas | Published: September 18, 2026 | Last Updated: October 16, 2026

My family has been acquiring and operating mineral interests in Comanche and Eastland Counties for multiple generations. I studied biology and chemistry at UT Arlington and now facilitate acquisitions of producing mineral and royalty interests for qualified buyers across Texas through Texas State Royalties LLC. The most common mistake I see from first-time buyers is conflating different types of mineral interests — particularly confusing an overriding royalty interest (ORRI) with a fee mineral interest, or misidentifying a non-participating royalty interest (NPRI) in an estate proceeding. This guide covers the full landscape: what mineral interests are, how they are structured, how royalties flow, and what every buyer needs to understand before committing capital.

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Quick Answer: A mineral interest is a real property ownership stake in the oil, gas, and other minerals beneath a tract of land, separate from surface ownership. Under the Texas Natural Resources Code, mineral interests are perpetual unless expressly limited by deed. When leased to an operator, the mineral owner receives royalty payments — a contractual share of production revenue — without bearing drilling or operating costs. The royalty fraction is set in the lease; the decimal interest is the royalty fraction multiplied by the owner's fractional share of the mineral estate.

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What Is a Mineral Interest?

A mineral interest is an ownership stake in the subsurface resources beneath a tract of land — the oil, natural gas, coal, metals, and other minerals that exist below the surface. Under Texas Property Code § 1.002, mineral interests are classified as real property, which means they are recorded in the county deed records, transfer by deed, and can be bought, sold, inherited, and exchanged just like surface real estate.

In the United States, and particularly in Texas, mineral interests can be owned separately from the surface of the land itself. This separation is called the severance of the mineral estate from the surface estate, and it is one of the most important concepts in American property law. When you own a mineral interest, you own a portion of whatever is extracted from beneath that land. If an operator drills a well and produces oil, you receive a share of the revenue from that production — typically in the form of a royalty payment — without bearing the costs of drilling or operating the well.

This is fundamentally different from owning stock in an oil company. You are not buying equity in a business. You are buying a real property interest in the ground itself — an interest that is recorded in the county deed records and that runs with the land in perpetuity unless expressly limited by the deed that created it.

What Is the Severed Estate and Why Does It Matter for Buyers?

To understand mineral interests, you need to understand how Texas property law treats land ownership. When someone owns land in fee simple — the most complete form of ownership — they own everything from the surface down to the center of the earth and up into the airspace above. This bundle of rights includes the right to use the surface, the right to build on it, and the right to extract minerals from beneath it.

At some point in the chain of title, a prior owner may have severed the mineral estate from the surface estate — conveying the surface to one party and retaining the minerals, or conveying the minerals to one party and retaining the surface. Once severed, the mineral estate and the surface estate are separate properties with separate owners, separate deeds, and separate chains of title. This severance is permanent and runs with the land.

Under the Texas Natural Resources Code, the mineral estate is the dominant estate in Texas — meaning the mineral owner has the right to use as much of the surface as is reasonably necessary to develop the minerals, even over the surface owner's objection. If you buy the surface of a tract today, you may not own the minerals beneath it. In producing areas of Texas, the majority of mineral interests have been severed from the surface and passed through multiple chains of title over generations.

For buyers, this means title research is not optional. The mineral interest you are acquiring may have been subdivided, partially conveyed, or encumbered by prior reservations that reduce the stated ownership fraction. In Palo Pinto and Comanche Counties, I have reviewed deed chains where prior reservations reduced the seller's stated ownership by 25% or more. The deed records are the authoritative source — not the seller's summary.

What Are the Different Types of Mineral Interests?

Not all mineral interests are the same. The oil and gas industry has developed a layered system of interests, each with different rights, obligations, and economic characteristics. Understanding these distinctions is the most important due diligence step a buyer can take.

Fee Mineral Interest (Mineral Rights)

The fee mineral interest — often called simply "mineral rights" — is the most fundamental and most valuable form of ownership. The mineral fee owner owns the minerals in place beneath the land under the Texas Natural Resources Code. They have the right to lease those minerals to an oil company for exploration and development, and they receive a royalty on any production that results. Fee mineral interests are perpetual — they survive lease expiration and remain valid indefinitely unless expressly limited by the creating deed.

Royalty Interest

A royalty interest is the right to receive a fraction of the gross production from a well, free of the costs of production. Royalty interests are typically created when a mineral owner signs an oil and gas lease with an operator. The lease grants the operator the right to drill and produce, and in exchange, the mineral owner retains a royalty — commonly 3/16 (18.75%) to 1/4 (25%) of gross production in active Texas plays today.

Royalty interests are passive. The royalty owner receives their share of production revenue without any obligation to pay for drilling, completion, or operating costs.

Non-Participating Royalty Interest (NPRI)

A non-participating royalty interest (NPRI) is a royalty interest carved out of the mineral fee and conveyed separately. The NPRI owner receives a royalty on production but has no right to lease the minerals, no right to sign leases, and no right to receive bonus payments or delay rentals from leasing activity.

NPRIs are common in Texas and frequently appear in estate proceedings. The most common confusion I encounter in estate proceedings is heirs misidentifying an NPRI as a full fee mineral interest. An NPRI owner has no leasing rights and no bonus income — only a royalty on production if and when the mineral fee owner leases and the operator drills. Under the Texas Estates Code, NPRIs pass through intestate succession the same as other real property interests, but their economic characteristics are fundamentally different from fee mineral interests. Buyers must examine the source document — the deed that created the NPRI — to understand its exact scope and limitations.

Overriding Royalty Interest (ORRI)

An overriding royalty interest (ORRI) is a royalty interest carved out of the working interest under a specific lease. ORRIs are typically created when a landman, geologist, or other party who helped assemble a lease receives a small royalty in exchange for their contribution.

The critical distinction for buyers: ORRIs exist only for the duration of the lease under which they were created. When the lease expires or terminates, the ORRI disappears. This makes ORRIs fundamentally different from fee mineral interests, which are perpetual. In the Fort Worth Basin, confusing an ORRI with a fee mineral interest is the most common due diligence mistake I see in acquisition packages. Both generate the same monthly royalty check while the lease is in force — but an ORRI has no value after the lease expires, while a fee mineral interest survives and can be re-leased. Buyers who do not examine the source document may pay mineral-interest prices for a lease-dependent ORRI. For a full breakdown of interest types and how to distinguish them, see Types of Mineral Interests: A Buyer's Reference.

Term Mineral Interest

A term mineral interest is a fee mineral interest that is limited in duration by the creating deed — for example, "for a period of 20 years and so long thereafter as oil or gas is produced." Term mineral interests appear with some regularity in Comanche and Eastland County deed chains from the mid-twentieth century. Before acquiring an interest in those counties, verify whether the interest is perpetual or term, confirm the remaining term, and check whether the deed contains a savings clause that extends the term upon production. A term interest approaching expiration without established production may have little or no value.

Working Interest

The working interest is the operating interest in an oil and gas lease — the interest that bears the cost of drilling, completing, and operating wells. Working interest owners receive a share of production revenue, but only after paying their proportionate share of all costs. Working interests are fundamentally different from royalty interests in their risk profile: a working interest owner can lose money if a well is unproductive or if operating costs exceed revenue. Texas State Royalties does not facilitate working interest acquisitions — buyers asking about working interests are redirected to operators and working interest brokers.

How Are Royalty Payments Calculated?

Understanding how royalty payments are calculated is essential for evaluating a mineral interest acquisition. The calculation involves several variables, and the specific terms of the oil and gas lease govern how each is applied.

At its simplest, a royalty payment is calculated as:

Royalty Payment = Production Volume × Commodity Price × Decimal Interest − Post-Production Deductions

Production volume is the amount of oil or gas produced from the well during the payment period, typically one month. Oil is measured in barrels (Bbls); gas is measured in thousand cubic feet (Mcf).

Commodity price is the price per unit of production at the applicable sales point — typically an index price (WTI for Permian oil, Henry Hub for gas) adjusted for any basis differential. Buyers should request actual price realizations from the seller's royalty statements rather than relying on index prices alone.

The decimal interest is the product of the royalty fraction and the mineral owner's fractional share of the mineral estate. A mineral owner with a 1/4 royalty who owns 40 net mineral acres in a 640-acre unit has a decimal interest of 0.25 × (40 ÷ 640) = 0.015625. Decimal interest errors are common in estate proceedings involving fractional mineral interests — a 1/4 royalty fraction on a 1/8 mineral ownership yields 0.03125, not 0.25. Always verify the decimal interest on the royalty statement against your own calculation.

Post-production deductions are costs incurred after the oil or gas leaves the wellhead — gathering, transportation, processing, and compression fees. Whether these costs can be deducted from your royalty depends on the language of the lease. On Fort Worth Basin Barnett Shale leases from the early 2000s lacking "free of cost" language, deductions of $0.35–$0.60/Mcf are common, reducing the effective royalty by 15–25% of gross value. Texas also imposes severance tax on production — 4.6% on oil and 7.5% on gas per the Texas Comptroller of Public Accounts — which is deducted before the royalty reaches the mineral owner.

For a complete explanation of royalty mechanics, post-production deductions, and royalty statement verification, see Understanding Oil and Gas Royalties: How Payments Are Calculated and What Reduces Them.

What Title Issues Do Buyers Encounter Most Often?

Title is where most mineral interest acquisitions go wrong. The mineral estate in Texas has been subdivided, conveyed, reserved, and inherited across generations, and the deed records in many counties reflect that complexity.

Unestablished heirship is the most common title defect I encounter in Comanche and Eastland County acquisitions. When a mineral interest owner dies without a recorded deed conveying the interest, the interest passes to heirs under the Texas Estates Code — but those heirs may not have recorded an affidavit of heirship or obtained a court order establishing their ownership. The result is a gap in the chain of title that must be resolved before a clean deed can be delivered. Buyers who skip the title opinion step may acquire an interest with a defective chain of title that cannot be insured or re-leased.

Prior reservations are another common issue. In Palo Pinto and Comanche Counties, I have reviewed deed chains where a prior grantor reserved a fraction of the minerals in a conveyance — reducing the seller's actual ownership below what they believe they own. A seller who believes they own 1/2 of the minerals may actually own 3/8 after accounting for a 1/8 reservation made two conveyances back. The only way to identify prior reservations is to run the full chain of title from the original patent.

Fractional ownership is the norm in Comanche and Eastland Counties, where a single tract may have a dozen or more fractional mineral owners. Each fractional owner's interest must be separately identified, verified, and conveyed. Buyers acquiring a fractional interest in a heavily subdivided tract should understand that their decimal interest may be very small — and that the royalty income will reflect that fraction.

NPRI confusion in estate proceedings is common when heirs inherit a mineral interest through an estate. Heirs frequently misidentify an NPRI as a full fee mineral interest, believing they have leasing rights and bonus income when they do not. Before acquiring any interest that originated in an estate proceeding, verify the source document and confirm whether the interest is a fee mineral interest, an NPRI, or an ORRI.

Before closing on any mineral interest acquisition, obtain a title opinion from a licensed Texas oil and gas attorney. The title opinion confirms that the seller owns what they are selling, identifies any defects in the chain of title, and is the foundation for any title insurance policy.

How Are Mineral Interests Valued?

Mineral interest valuation depends primarily on whether the interest is producing or non-producing, and on the basin, operator, and production profile of the associated wells.

Producing interests are valued based on current royalty income, projected decline curve, commodity price assumptions, and the buyer's required rate of return. Producing Permian Basin interests currently trade at 40–60x monthly royalties, reflecting the oil-weighted production profile and strong operator activity. Fort Worth Basin Barnett Shale interests trade at 30–45x monthly royalties, reflecting the gas-weighted production profile and greater commodity price uncertainty. Buyers applying a discounted cash flow approach typically use a 10–15% discount rate for Permian cash flows and 15–20% or higher for Barnett Shale gas.

Non-producing interests — acreage with no current production — are valued based on the probability of future drilling activity, the quality of the formation, and the operator's development plans. Producing Permian interests trade at roughly 8–15x the value of non-producing Permian interests in the same area, reflecting the development risk premium.

Under SEC Regulation S-X, Rule 4-10, working interest owners classify reserves as Proved Developed Producing (PDP), Proved Undeveloped (PUD), or Probable. Royalty interest owners are not subject to the same reserve reporting requirements, but the PDP/PUD framework is a useful lens for evaluating the upside component of any acquisition.

How Are Mineral Interests Taxed?

Under IRS Publication 535, royalty income from mineral interests is ordinary income for federal tax purposes. However, royalty interest owners who qualify as independent producers or royalty owners may deduct percentage depletion at 15% of gross income from the property, subject to the limitation that the deduction cannot exceed 100% of net income from the property. This depletion deduction is one of the primary tax advantages of owning a royalty interest rather than a working interest.

When a mineral interest is sold, the gain from the sale may qualify for a 1031 like-kind exchange, allowing the seller to defer capital gains tax by reinvesting the proceeds into a replacement mineral interest. Mineral interests are classified as real property under federal tax law, which makes them eligible for 1031 treatment. For a complete guide, see Understanding 1031 Exchanges for Mineral Interests.

The tax treatment of mineral interests is complex. Consult a licensed CPA with oil and gas experience before making any acquisition or disposition decision.

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Key Takeaways

• A mineral interest is a real property ownership stake in the oil, gas, and other minerals beneath a tract of land, classified as real property under Texas Property Code § 1.002. Fee mineral interests are perpetual under the Texas Natural Resources Code — they survive lease expiration and remain valid indefinitely unless expressly limited by the creating deed.

• The most critical distinction for buyers is between a fee mineral interest (perpetual, survives lease expiration, carries leasing rights) and an overriding royalty interest (ORRI — lease-dependent, expires when the underlying lease terminates, no leasing rights). In the Fort Worth Basin, confusing an ORRI with a fee mineral interest is the most common due diligence mistake. Both generate the same monthly check while the lease is in force; only the fee mineral interest has value after the lease expires.

• NPRIs are frequently misidentified as full fee mineral interests in estate proceedings. An NPRI owner has no leasing rights, no bonus income, and no right to sign leases — only a royalty on production if and when the mineral fee owner leases and the operator drills. Verify the source document before acquiring any interest that originated in an estate proceeding.

• Unestablished heirship is the most common title defect in Comanche and Eastland County acquisitions. Prior reservations in Palo Pinto and Comanche County deed chains have reduced sellers' stated ownership by 25% or more in transactions I have reviewed. A title opinion from a licensed Texas oil and gas attorney is not optional — it is the foundation of a clean acquisition.

• The decimal interest is the royalty fraction multiplied by the owner's fractional share of the mineral estate. Decimal interest errors are common in estate proceedings involving fractional mineral interests. A 1/4 royalty fraction on a 1/8 mineral ownership yields 0.03125, not 0.25. Always verify the decimal interest on the royalty statement against your own calculation before signing a division order.

• Producing Permian Basin interests currently trade at 40–60x monthly royalties; Fort Worth Basin Barnett interests at 30–45x. Buyers apply a 10–15% discount rate to Permian cash flows and 15–20% or higher to Barnett Shale gas. Producing Permian interests trade at roughly 8–15x the value of non-producing interests in the same area.

• Royalty income from mineral interests is eligible for percentage depletion at 15% under IRS Publication 535, subject to the 100%-of-net-income limitation. Texas also imposes severance tax — 4.6% on oil and 7.5% on gas per the Texas Comptroller — which is deducted before the royalty reaches the mineral owner. Consult a licensed CPA with oil and gas experience before acquiring.

• Reserve classifications follow SEC Regulation S-X Rule 4-10; the PV10 income approach — discounting future net cash flows at 10% — is the standard framework for valuing producing mineral interests

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Frequently Asked Questions

What is the difference between a mineral interest and a royalty interest? A mineral interest (fee mineral interest) is perpetual ownership of the mineral estate itself — the right to the minerals in place, the right to lease them, and the right to receive bonus payments and royalties. A royalty interest is the right to receive a fraction of production revenue, free of costs, created when the mineral owner signs a lease. The mineral owner retains the royalty interest as part of the lease transaction. The two terms are often used interchangeably in casual conversation, but they are legally distinct: a mineral interest is the underlying property right; a royalty interest is one of the economic rights that flows from it. For a full breakdown of all interest types, see Types of Mineral Interests: A Buyer's Reference.

What is an overriding royalty interest (ORRI) and why is it riskier than a fee mineral interest? An overriding royalty interest (ORRI) is a royalty interest carved out of the working interest under a specific lease. It generates the same monthly royalty check as a fee mineral interest while the lease is in force — but it expires when the lease terminates. A fee mineral interest is perpetual and can be re-leased after expiration; an ORRI has no value after the lease ends. In the Fort Worth Basin, confusing an ORRI with a fee mineral interest is the most common due diligence mistake in acquisition packages. Always examine the source document — the deed or assignment that created the interest — to confirm whether you are acquiring a perpetual fee mineral interest or a lease-dependent ORRI.

What title defects are most common in Texas mineral interest acquisitions? The most common title defect in Comanche and Eastland County acquisitions is unestablished heirship — a gap in the chain of title where a mineral interest owner died without a recorded deed conveying the interest to their heirs. Prior reservations are also common: in Palo Pinto and Comanche Counties, prior grantors have reserved fractions of the minerals in conveyances, reducing the seller's actual ownership below what they believe they own. Fractional ownership is the norm in those counties, where a single tract may have a dozen or more fractional mineral owners. A title opinion from a licensed Texas oil and gas attorney is the only reliable way to identify these defects before closing.

How are mineral interests taxed at the federal level? Royalty income from mineral interests is ordinary income for federal tax purposes. Royalty interest owners who qualify as independent producers or royalty owners may deduct percentage depletion at 15% of gross income from the property under IRS Publication 535, subject to the limitation that the deduction cannot exceed 100% of net income from the property. When a mineral interest is sold, the gain may qualify for a 1031 like-kind exchange, deferring capital gains tax by reinvesting proceeds into a replacement mineral interest. Texas also imposes severance tax on production — 4.6% on oil and 7.5% on gas — which is deducted before the royalty reaches the mineral owner. Consult a licensed CPA with oil and gas experience before acquiring.

What valuation multiples do producing mineral interests trade at in Texas? Producing Permian Basin interests currently trade at 40–60x monthly royalties, reflecting the oil-weighted production profile and strong operator activity. Fort Worth Basin Barnett Shale interests trade at 30–45x monthly royalties, reflecting the gas-weighted production profile and greater commodity price uncertainty for natural gas. Buyers applying a discounted cash flow approach typically use a 10–15% discount rate for Permian cash flows and 15–20% or higher for Barnett Shale gas. Non-producing Permian interests trade at roughly 1/8 to 1/15 of producing interest values in the same area, reflecting the development risk premium.

How does Texas State Royalties help buyers acquire mineral interests? Texas State Royalties facilitates acquisitions of producing fee mineral interests for qualified buyers across Texas. We source opportunities, review production history against Texas Railroad Commission records, analyze lease terms and post-production cost provisions, and walk buyers through the decimal interest verification, title opinion, and division order process from initial identification through deed conveyance and first royalty payment. We work exclusively with buyers, not sellers. Learn more about how we work with buyers or review our acquisition and facilitation services.

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Texas State Royalties sources and facilitates acquisitions of producing mineral and royalty interests across Texas for qualified buyers. Learn more about how we work with buyers or review our acquisition and facilitation services.

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This article is for educational purposes only and is not legal, tax, or investment advice. The legal and tax characteristics of mineral interests vary by state and by the specific terms of each deed and lease. Consult a qualified Texas oil and gas attorney and a licensed CPA before making any acquisition decision.

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About the Author

Richard Partin is the founder of Texas State Royalties, a Fort Worth-based, buyer-first firm that sources producing oil and gas mineral interests through established industry relationships. His website biography describes years of hands-on experience in oil and gas, including acreage interests, working interests, and capital formation across active producing regions nationwide.

TSR works with buyers to understand their criteria, source and screen opportunities, and review available information about location, production and revenue history, operator, and ownership documentation. Buyers review the details and decide whether to proceed. When a transaction moves forward, the mineral interest is conveyed by deed.

Texas State Royalties works with buyers and facilitates direct mineral-interest deed conveyances. TSR is not a neutral advisor, and its materials reflect its role in helping buyers source and review opportunities. Information is for educational purposes only and is not legal, tax, or investment advice. TSR does not determine whether a particular mineral interest qualifies as replacement property for a 1031 exchange. Buyers should consult their Qualified Intermediary and qualified tax, legal, and financial advisors before making a decision.