Different Types of Mineral Interests: A Buyer\'s Reference

By Richard Partin, Managing Member, Texas State Royalties LLC Fort Worth, Texas | Published: October 9, 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 due diligence mistake I see in Fort Worth Basin acquisitions is confusing an overriding royalty interest with a mineral interest — a distinction that can mean the difference between a perpetual income stream and one that expires with the next lease. Understanding the types of mineral interests is the foundation of any responsible acquisition.

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Quick Answer: The main types of mineral interests in Texas are: fee mineral interests (perpetual ownership of the subsurface), royalty interests (lease-created revenue share, no costs), working interests (operating interest with cost obligations), overriding royalty interests (lease-dependent, carved from working interest), and non-participating royalty interests (perpetual revenue share, no leasing rights). Most buyers acquiring income-producing interests target fee mineral interests or NPRIs — both are perpetual and cost-free.

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The phrase "mineral interest" covers a broad category of ownership rights in the oil and gas beneath a tract of land. But within that category, there are several distinct types of interests — each with different rights, different obligations, and different economic characteristics.

A buyer who acquires a royalty interest is acquiring something fundamentally different from a buyer who acquires a working interest. An overriding royalty interest carries different rights than a non-participating royalty interest. Understanding these distinctions is not a technical detail — it is essential knowledge for any buyer evaluating a mineral interest acquisition.

For a foundational overview of what mineral interests are and how they fit into the broader structure of oil and gas ownership, see Understanding Mineral Interests: The Complete Guide for Buyers.

What Is the Mineral Estate and Why Does It Matter?

Before examining the specific types of interests, it helps to understand the mineral estate itself.

The mineral estate is the ownership of the subsurface resources — the oil, gas, and other minerals — beneath a tract of land, as defined under Texas Property Code § 1.002 and governed by the Texas Natural Resources Code. In Texas, the mineral estate can be severed from the surface estate and owned separately. Once severed, the mineral estate can be further divided, leased, and conveyed in a variety of ways.

The various types of mineral interests described below all derive from the mineral estate. Some represent ownership of the mineral estate itself. Others are created by the oil and gas lease that a mineral owner signs with an operator. The distinction between perpetual interests (those that survive lease expiration) and lease-dependent interests (those that expire when the lease terminates) is the most important classification for buyers to understand.

For a detailed explanation of how the mineral estate is separated from the surface estate, see Mineral Rights vs. Surface Rights: What Every Buyer Needs to Know.

What Is a Fee Mineral Interest and What Rights Does It Include?

A fee mineral interest — sometimes called simply a mineral interest or minerals — is ownership of the mineral estate itself. This is the foundational interest from which all other interests derive.

A fee mineral interest owner holds:

• The right to execute an oil and gas lease with an operator
• The right to receive a bonus payment when a lease is signed
• The right to receive royalty payments when production generates revenue under the terms of the lease
• The right to develop the minerals themselves (though most mineral interest owners lease rather than operate)
• The right to sell, transfer, or devise the interest

Fee mineral interests are perpetual — they do not expire. An unleased mineral interest remains valid indefinitely under Texas law, regardless of whether any development has occurred. This perpetual character is what distinguishes a fee mineral interest from an overriding royalty interest, which expires when the underlying lease terminates.

Fee mineral interests can be divided fractionally. A single tract may have dozens of mineral interest owners, each holding a fractional share of the mineral estate. In my experience examining title chains in Comanche and Eastland Counties, fractional mineral interests are extremely common — a single 640-acre section may have fifteen or more fractional owners, each holding a small decimal interest. When a lease is signed, each owner's royalty is proportional to their fractional ownership of the mineral estate.

The Texas Railroad Commission maintains production records that allow buyers to verify the production history associated with a mineral interest before acquiring. Cross-checking a seller's income summary against RRC production data is a standard step in any responsible due diligence process.

What Is a Royalty Interest and How Is It Different from a Mineral Interest?

A royalty interest is the right to receive a share of production revenue from an oil and gas well, free of the costs of production. Royalty interests are created by the oil and gas lease — when a mineral owner leases their interest to an operator, the lease specifies the royalty fraction the mineral owner will receive.

Key characteristics of a royalty interest:

• No operating costs. The royalty interest owner receives their share of production revenue without bearing any of the costs of drilling, completion, or production operations.
• No capital calls. The royalty interest owner is never asked to contribute capital for drilling or workover operations.
• Revenue tied to production. Royalty payments are made when the operator produces and sells oil or gas from the leased acreage. If production declines or stops, royalty payments decline or stop accordingly.
• Subject to post-production deductions. Depending on the lease terms and applicable Texas law, the royalty may be subject to deductions for gathering, transportation, processing, and marketing costs incurred after the oil or gas leaves the wellhead. On Fort Worth Basin Barnett Shale leases from the early 2000s — many of which lack "free of cost" language — gathering and processing deductions of $0.35–$0.60/Mcf are common, reducing the effective royalty by 15–25% of gross value.

The royalty fraction is specified in the lease. Common royalty fractions in Texas range from one-eighth (12.5%) to one-fourth (25%). The royalty fraction applies to the mineral owner's decimal interest, which is calculated based on their fractional ownership of the mineral estate multiplied by the royalty rate in the lease.

Under IRS Publication 535, royalty income from mineral interests is subject to depletion — either cost depletion or percentage depletion at 15% for independent producers and royalty owners. This tax treatment is one of the economic advantages of owning a royalty interest rather than a working interest.

For a detailed explanation of how royalty payments are calculated, see How Royalty Payments Are Calculated.

What Is a Working Interest and Why Don't Most Buyers Acquire One?

A working interest is the operating interest in an oil and gas lease — the interest held by the party responsible for drilling, completing, and operating the well. The working interest owner bears the costs of development and production in exchange for the right to the production revenue remaining after the royalty is paid.

Key characteristics of a working interest:

• Operating obligation. The working interest owner is responsible for all costs of drilling, completion, and production. These costs can be substantial and are borne before any revenue is received.
• Revenue after royalty. The working interest owner receives the production revenue remaining after the royalty is paid to the mineral owner. This is called the net revenue interest.
• Capital exposure. Unlike a royalty interest, a working interest carries real financial risk. If a well is drilled and produces nothing, the working interest owner bears the full cost of the dry hole.
• Operational control. The working interest owner (or the operator designated among working interest owners) makes the decisions about when and how to develop the acreage.

Working interests are fundamentally different from royalty interests in their risk profile. A royalty interest owner receives revenue when production occurs but bears no operating costs. A working interest owner bears all operating costs and receives revenue only after those costs are recovered.

Texas State Royalties facilitates acquisitions of mineral interests and royalty interests — not working interests. Buyers who contact us asking about working interests are redirected, because the cost obligations and operational complexity of a working interest are outside the scope of what we facilitate. The distinction matters for setting expectations before any acquisition conversation begins.

Under SEC Regulation S-X, Rule 4-10, working interest owners are required to classify their reserves as Proved Developed Producing (PDP), Proved Undeveloped (PUD), or Probable — a classification system that does not apply to royalty interest owners in the same way, since royalty owners bear no development costs.

What Is an Overriding Royalty Interest (ORRI) and Why Is It Riskier Than a Mineral Interest?

An overriding royalty interest (ORRI) is a non-operating interest in an oil and gas lease that entitles the holder to a share of production revenue, free of production costs, carved out of the working interest rather than the mineral estate.

Key characteristics of an ORRI:

• Created from the working interest. An ORRI is carved out of the lessee's working interest, not from the mineral estate itself. It is created by the lessee and assigned to a third party — commonly a geologist, landman, or financier in exchange for services or capital.
• Tied to the lease. An ORRI exists only as long as the underlying lease is in effect. When the lease expires or terminates, the ORRI expires with it. This is the critical distinction between an ORRI and a mineral interest: a mineral interest is perpetual, while an ORRI is lease-dependent.
• No operating costs. Like a royalty interest, an ORRI is free of production costs. The ORRI holder receives their share of production revenue without bearing any drilling or operating expenses.
• No leasing rights. An ORRI holder has no right to execute a new lease when the current lease expires. If the mineral owner chooses not to re-lease the acreage, the ORRI holder receives nothing.

Confusing an ORRI with a mineral interest is the most common due diligence mistake I see in Fort Worth Basin acquisitions. Buyers who do not examine the source document — the assignment creating the ORRI — may believe they are acquiring a perpetual mineral interest when they are actually acquiring a lease-dependent interest that could expire within a few years. The difference in value between a perpetual mineral interest and an ORRI on the same acreage can be substantial, particularly on Barnett Shale leases from the early 2000s that are approaching the end of their held-by-production status.

For buyers evaluating an ORRI, the lease-dependent nature of the interest is the most important consideration. Always verify the underlying lease's primary term, held-by-production status, and expiration date before assigning value to an ORRI.

What Is a Non-Participating Royalty Interest (NPRI) and How Does It Affect Buyers?

A non-participating royalty interest (NPRI) is a royalty interest carved out of the mineral estate that entitles the holder to a share of production revenue but does not include the right to participate in leasing decisions, receive bonus payments, or execute leases.

Key characteristics of an NPRI:

• Perpetual. Unlike an ORRI, an NPRI is carved out of the mineral estate itself and survives lease expiration. When the current lease expires and a new lease is signed, the NPRI holder continues to receive their royalty share under the new lease.
• No leasing rights. The NPRI holder has no executive rights — no right to negotiate lease terms, receive bonus payments, or control when or how the acreage is leased. Those rights remain with the mineral interest owner.
• No operating costs. The NPRI holder receives production revenue free of drilling and operating costs, just as a royalty interest owner does.
• Fixed or floating fraction. An NPRI may be expressed as a fixed fraction of production (e.g., 1/16 of all production) or as a floating fraction tied to the lease royalty (e.g., 1/4 of the lease royalty). The distinction matters significantly for calculating the NPRI holder's income under different lease terms.

In estate proceedings involving Texas mineral interests, NPRI confusion is common. Heirs frequently misidentify an NPRI as a full mineral interest — overstating the value of the estate by attributing leasing rights and bonus income to an interest that carries neither. A careful review of the deed creating the NPRI is essential before assigning value in any estate or acquisition context.

What Are Term Mineral Interests and Executive Rights?

Term mineral interests are mineral interests limited in duration — they expire after a specified period or upon the occurrence of a specified condition. Term mineral interests appear in Texas deed records, particularly in Comanche and Eastland County chains from the mid-twentieth century. A buyer evaluating a term mineral interest must verify the remaining term, any savings clauses that extend the term upon production, and what happens to the mineral estate at expiration.

Executive rights are the rights associated with leasing the mineral estate — the right to execute a lease, negotiate lease terms, and receive bonus payments. Executive rights are a component of the mineral estate and can be separated from the royalty rights. When executive rights are separated, the result is a split between the party who controls leasing decisions (the executive rights holder) and the party who receives royalty income (the NPRI holder). A mineral interest without executive rights gives the buyer no control over when or how the acreage is leased — a material limitation that should be reflected in the acquisition price.

Summary: Key Distinctions for Buyers

Interest Type	Created From	Perpetual?	Leasing Rights?	Operating Costs?
Fee Mineral Interest	Mineral estate	Yes	Yes	No
Royalty Interest	Oil and gas lease	No (lease-dependent)	No	No
Working Interest	Oil and gas lease	No (lease-dependent)	Yes (as lessee)	Yes
ORRI	Working interest	No (lease-dependent)	No	No
NPRI	Mineral estate	Yes	No	No
Term Mineral Interest	Mineral estate	No (expires)	Yes	No

The most important distinction for most buyers is between interests that are perpetual (fee mineral interests and NPRIs) and interests that are lease-dependent (royalty interests, working interests, and ORRIs). A perpetual interest survives the expiration of any particular lease. A lease-dependent interest expires when the lease terminates.

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Key Takeaways

• The six primary types of mineral interests in Texas are: fee mineral interests, royalty interests, working interests, overriding royalty interests (ORRIs), non-participating royalty interests (NPRIs), and term mineral interests. Each carries different rights, obligations, and economic characteristics under the Texas Natural Resources Code and Texas Property Code § 1.002.

• Fee mineral interests and NPRIs are perpetual — they survive lease expiration and remain valid indefinitely. Royalty interests, working interests, and ORRIs are lease-dependent — they expire when the underlying lease terminates. This is the most important classification for buyers to understand before acquiring any interest.

• Confusing an ORRI with a mineral interest is the most common due diligence mistake in Fort Worth Basin acquisitions. An ORRI is carved from the working interest and expires with the lease; a mineral interest is perpetual. Buyers who do not examine the source document may pay mineral-interest prices for a lease-dependent ORRI.

• Royalty interest owners receive production revenue free of operating costs and are eligible for percentage depletion at 15% under IRS Publication 535. Working interest owners bear all drilling and operating costs and receive revenue only after those costs are recovered — a fundamentally different risk profile.

• On Fort Worth Basin Barnett Shale leases from the early 2000s lacking "free of cost" language, post-production deductions of $0.35–$0.60/Mcf are common, reducing the effective royalty by 15–25% of gross value. Buyers must review the lease terms — not just the royalty fraction — to understand actual net revenue.

• NPRIs are perpetual but carry no executive rights — the NPRI holder cannot negotiate lease terms, receive bonus payments, or control when the acreage is leased. In estate proceedings, NPRIs are frequently misidentified as full mineral interests, overstating the estate's value by attributing leasing rights and bonus income that the NPRI does not carry.

• The Texas Railroad Commission production database allows buyers to verify production history for any mineral interest before acquiring. Cross-checking a seller's income summary against RRC data is a standard due diligence step — seller summaries frequently reflect the best production months and omit low-production periods.

• The Texas Comptroller imposes severance tax at 4.6% on oil and 7.5% on gas; reserve classifications follow SEC Regulation S-X Rule 4-10; under Texas Estates Code, mineral interests held individually pass through probate at death — unestablished heirship is the most common title defect in Comanche and Eastland County acquisitions

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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 ownership of the mineral estate itself — a perpetual property right that includes the right to lease the acreage, receive bonus payments, and receive royalty income. A royalty interest is created by the oil and gas lease and entitles the holder to a share of production revenue free of costs, but it exists only as long as the lease is in effect. When the lease expires, the royalty interest expires with it. The mineral interest owner retains the right to execute a new lease; the royalty interest holder does not.

What is the difference between an ORRI and a mineral interest? An overriding royalty interest (ORRI) is carved out of the working interest under a specific oil and gas lease and entitles the holder to a share of production revenue free of costs — but only for as long as that lease remains in effect. When the lease expires, the ORRI expires with it. A mineral interest is perpetual and survives lease expiration. Buyers should always verify whether they are acquiring a mineral interest or an ORRI, as the two have fundamentally different values and risk profiles. Confusing the two is the most common due diligence mistake in Fort Worth Basin acquisitions.

What is a non-participating royalty interest (NPRI) and is it perpetual? A non-participating royalty interest (NPRI) is a royalty interest carved out of the mineral estate — not the working interest — that entitles the holder to a share of production revenue free of costs. Unlike an ORRI, an NPRI is perpetual: it survives lease expiration and continues under any new lease signed on the same acreage. However, an NPRI carries no executive rights — the NPRI holder cannot negotiate lease terms, receive bonus payments, or control when the acreage is leased. Those rights remain with the mineral interest owner.

Do mineral interests expire if no drilling occurs? A fee mineral interest in Texas does not expire simply because no development has occurred. An unleased mineral interest remains valid indefinitely under Texas law. An oil and gas lease, however, does have a defined primary term — typically one to five years — after which it expires if production has not been established. The mineral interest itself is perpetual; the lease is not. Term mineral interests are an exception: they are mineral interests limited in duration by the deed that created them, and they do expire upon the specified date or condition.

How are royalty interests taxed under federal law? Under IRS Publication 535, royalty income from mineral interests is subject to depletion. Royalty interest owners who are 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. Working interest owners are subject to cost depletion rather than percentage depletion in most circumstances, and they may also deduct intangible drilling costs (IDCs) in the year incurred. The tax treatment of mineral interests is complex; consult a licensed CPA with oil and gas experience before making any acquisition decision.

What does Texas State Royalties facilitate, and which interest types are included? Texas State Royalties facilitates acquisitions of fee mineral interests — perpetual, fractional ownership stakes in the mineral estate beneath producing Texas acreage. We do not facilitate working interest acquisitions. Buyers who contact us asking about working interests are redirected, because the cost obligations and operational complexity of a working interest are outside the scope of what we facilitate. Every interest we bring to buyers has been sourced, reviewed for production history and lease terms, and structured for a clean deed conveyance. Learn more about how we work with buyers or review our acquisition and facilitation services.

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Start Your Buyer Search

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 characteristics of each interest type vary by state and by the specific language in a deed or 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.