What Is an Acreage Interest in Oil and Gas? A Complete Guide for Buyers

By Richard Partin, Managing Member, Texas State Royalties LLC Fort Worth, Texas | Published: September 21, 2026 | Last Updated: October 16, 2026

In my work facilitating mineral interest acquisitions across Texas, the most common source of buyer confusion is the difference between what a seller says they own and what the deed chain actually confirms. A seller may describe their interest as "40 net mineral acres in Reeves County" — but the deed chain may reveal prior reservations that reduce the actual ownership, or a term mineral interest with a limited remaining life. In Comanche and Eastland Counties, I routinely find prior reservations that reduce stated ownership by 25% or more. In Palo Pinto County, those reductions have been even larger in some deed chains I have reviewed. The acreage figure in the seller's summary is a starting point, not a guarantee. This guide explains what an acreage interest is, how net mineral acres are calculated, how royalty income flows from an acreage interest, and what buyers must verify before closing.

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Quick Answer: An acreage interest in oil and gas is a fractional ownership stake in the mineral rights beneath a described tract of land, measured in net mineral acres (NMA). Under Texas Property Code § 1.002, mineral interests are real property; ownership is established by deed recorded in the county deed records. Net mineral acres determine the royalty fraction a buyer receives when production occurs on the tract.

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What Is an Acreage Interest in Oil and Gas?

An acreage interest in oil and gas is a fractional ownership stake in the mineral rights associated with a tract of land — expressed in acres, but representing subsurface ownership rights rather than surface land. When you own an acreage interest, you own the right to explore for, produce, and receive royalties from oil, gas, and other minerals beneath the described tract.

Under Texas Property Code § 1.002, mineral interests are classified as real property. They are created, transferred, and extinguished through deeds recorded in the county deed records — the same system used for surface land. An acreage interest is not a surface ownership right. You do not own the land itself; you own the mineral estate beneath it.

The term "acreage interest" is used in the industry to describe mineral interests measured in net mineral acres — as opposed to royalty interests measured in decimal fractions or working interests measured in working interest percentages. When a buyer says they are acquiring "40 net mineral acres in Reeves County," they mean they are acquiring the mineral rights beneath a tract where their fractional ownership, multiplied by the gross acreage of the tract, equals 40 acres.

For a broader overview of the different types of mineral interests and how they are structured, see: Types of Mineral Interests in Texas.

How Are Net Mineral Acres Calculated?

Net mineral acres (NMA) are calculated by multiplying the gross acreage of the tract by the fractional mineral ownership. If a tract contains 640 gross acres and you own an undivided 1/4 of the mineral estate, you own 160 net mineral acres (640 × 0.25 = 160 NMA).

The calculation sounds straightforward — but in practice, it requires tracing the full chain of title to confirm the actual fractional ownership. In Texas, mineral interests have been divided and subdivided through generations of inheritance, sale, and reservation. A tract that was once owned by a single family may now have dozens of mineral owners, each holding a fraction of the original estate.

Prior reservations in the deed chain are the most common source of discrepancy between stated and actual ownership. In Comanche, Eastland, and Palo Pinto Counties, prior grantors have reserved fractions of the minerals in conveyances made generations ago. The current seller may genuinely believe they own the full stated interest — but the deed chain controls. I have reviewed Palo Pinto County deed chains where prior reservations reduced the seller's stated ownership by 25% or more. A title opinion from a licensed Texas oil and gas attorney is the only reliable way to confirm actual net mineral acres before closing.

Decimal interest errors are also common in estate proceedings. A 1/4 royalty on a 1/8 mineral interest equals a decimal of 0.03125, not 0.25. Always calculate and verify the decimal interest independently from the deed chain and the division order before closing.

How Does an Acreage Interest Generate Royalty Income?

An acreage interest generates royalty income when an operator drills and produces oil or gas from a well on the tract. The royalty income flows through the following chain:

1. The oil and gas lease. The mineral interest owner (or their predecessor) executed an oil and gas lease granting the operator the right to drill and produce. The lease specifies the royalty fraction — typically 1/5 (20%), 3/16 (18.75%), or 1/4 (25%) in modern Texas leases. Older leases in the Fort Worth Basin Barnett Shale from the early 2000s were often executed at 1/8 (12.5%) to 3/16 (18.75%) and are now held by production (HBP), meaning the lease terms are fixed and cannot be renegotiated until the lease expires.

2. The royalty calculation. The royalty payment is calculated as: gross production revenue × royalty fraction × net revenue interest (NRI). The NRI accounts for any overriding royalty interests (ORRIs) or other burdens on the lease that reduce the working interest owner's net revenue. For a mineral interest owner, the relevant fraction is the royalty fraction in the lease multiplied by the mineral ownership fraction.

3. Post-production deductions. Whether post-production costs (gathering, compression, processing, transportation) can be deducted from the royalty depends on the lease language. Leases that lack "free of cost" or "at the wellhead" language allow the operator to deduct these costs. In the Fort Worth Basin, Barnett Shale post-production deductions of $0.35–$0.60 per Mcf reduce the effective royalty by 15–25%. Buyers must review the lease language carefully before closing.

4. Severance tax. The Texas Comptroller imposes severance tax on production before the royalty reaches the mineral owner: 4.6% on oil and 7.5% on natural gas. These deductions appear on the royalty check statement.

5. Federal income tax. Royalty income is ordinary income for federal tax purposes. Qualifying royalty interest 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. Reserve classifications for producing properties follow SEC Regulation S-X Rule 4-10, which defines proved developed producing (PDP), proved developed non-producing (PDNP), and proved undeveloped (PUD) reserves.

What Is the Difference Between an Acreage Interest and a Royalty Interest?

An acreage interest (mineral interest) conveys the full bundle of mineral rights: the right to explore, the executive right to lease, the right to receive bonus payments, the right to receive royalties, and the right to sell or devise the interest. The owner of an acreage interest controls the leasing of the mineral estate.

A royalty interest conveys only the right to receive a fraction of production revenue — without the executive right to lease or negotiate lease terms. A royalty interest owner receives royalty payments when production generates revenue but has no control over the leasing of the mineral estate.

A non-participating royalty interest (NPRI) is a royalty interest that does not participate in lease bonuses or rentals — only in production royalties. NPRI confusion in estate proceedings is common: heirs sometimes misidentify an NPRI as a full mineral interest, leading to overstated ownership claims. In Comanche and Eastland County estate proceedings, I have encountered this confusion repeatedly. The creating deed is the authoritative source — not the division order, not the royalty check stub.

An overriding royalty interest (ORRI) is a royalty interest carved out of the working interest — it is not a mineral interest and does not survive lease expiration. ORRI vs. mineral interest confusion is the most common Fort Worth Basin due diligence mistake I encounter. A buyer who pays mineral interest prices for an ORRI is acquiring an interest that may expire when the current lease terminates.

For a detailed breakdown of the different types of mineral interests and what each conveys, see: Types of Mineral Interests in Texas.

What Are Term Mineral Interests and Why Do They Matter?

A term mineral interest is a mineral interest limited in duration — it expires at the end of a specified period unless production is occurring. Term mineral interests are common in Comanche and Eastland County deed chains, where prior grantors conveyed mineral interests for a fixed term (often 10 or 20 years) with a savings clause that extends the interest if production is established before expiration.

Buyers must verify the remaining term and confirm whether a savings clause extends the interest if production is established before expiration. An expired term mineral interest has no value, and the language in the creating deed is the only authoritative source for the term and savings clause provisions. I have reviewed Comanche County deed chains where term mineral interests had already expired — but the seller was unaware because the division order had never been updated.

What Should Buyers Verify Before Acquiring an Acreage Interest?

Before closing on any acreage interest acquisition, buyers should complete the following due diligence:

Confirm actual net mineral acres through a title opinion. Commission a title opinion from a licensed Texas oil and gas attorney. The title opinion should trace the full chain of title from the original patent, identify any prior reservations, confirm the fractional ownership, and flag any defects — unestablished heirship under the Texas Estates Code, missing spousal joinder, gaps in the chain, or term mineral interests with limited remaining life.

Verify production history against RRC records. Cross-reference the seller's production summary against Texas Railroad Commission (RRC) production records. Seller summaries often omit low-production months; discrepancies between the seller's summary and RRC data typically favor the seller. Use the RRC's production query system to pull the full production history for the relevant lease and well.

Review the oil and gas lease. Obtain and review the full lease. Confirm the royalty fraction, post-production cost provisions, depth clauses, and held-by-production status. Understand what you are acquiring subject to. In the Fort Worth Basin, Barnett Shale leases from the early 2000s — many HBP at 1/8 to 3/16 royalty and lacking "free of cost" language — carry post-production deductions of $0.35–$0.60 per Mcf, reducing the effective royalty by 15–25%.

Verify the decimal interest independently. Calculate the decimal interest from the deed chain and compare it to the division order. Decimal interest errors are common in estate proceedings. A 1/4 royalty on a 1/8 mineral interest equals 0.03125, not 0.25.

Understand the pricing framework. Producing Permian Basin interests typically trade at 40–60x monthly royalties; Fort Worth Basin Barnett Shale interests trade at 30–45x. Producing Permian interests trade at 8–15x the value of non-producing interests in the same basin. Buyers apply a 10–15% discount rate to Permian Basin interests and 15–20%+ to Barnett Shale gas interests, reflecting the higher decline risk of gas-weighted production.

Understand the Texas Natural Resources Code framework. The mineral estate is the dominant estate in Texas; the surface owner cannot unreasonably interfere with the mineral owner's right to develop. This framework governs the relationship between surface and mineral owners and is relevant to understanding the rights that come with an acreage interest acquisition.

Texas State Royalties works with buyers to source, screen, and facilitate acreage interest acquisitions across Texas. Start Your Buyer Search or review our acquisition services to learn how we structure the process from initial identification through deed conveyance and first royalty payment.

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Key Takeaways

• An acreage interest is a fractional ownership stake in the mineral estate beneath a described tract, measured in net mineral acres (NMA); under Texas Property Code § 1.002, it is real property established by recorded deed — not surface ownership
• In Comanche, Eastland, and Palo Pinto Counties, prior reservations in deed chains routinely reduce the seller's stated net mineral acres — I have reviewed Palo Pinto County deed chains where prior reservations reduced stated ownership by 25% or more; a title opinion from a licensed Texas oil and gas attorney is the only reliable way to confirm actual NMA before closing
• NPRI confusion in estate proceedings is common — heirs misidentify NPRIs as full mineral interests; ORRI vs. mineral interest confusion is the most common Fort Worth Basin due diligence mistake; the creating deed is the authoritative source, not the division order or royalty check stub
• Term mineral interests in Comanche and Eastland County require verification of remaining term and savings clause provisions; an expired term mineral interest has no value
• Fort Worth Basin Barnett Shale leases from the early 2000s — many HBP at 1/8 to 3/16 royalty and lacking "free of cost" language — carry post-production deductions of $0.35–$0.60 per Mcf, reducing effective royalty by 15–25%; buyers acquire the interest subject to the existing lease
• Royalty income is ordinary income; qualifying owners may deduct percentage depletion at 15% of gross income under IRS Publication 535; the Texas Comptroller imposes severance tax at 4.6% on oil and 7.5% on gas before the royalty reaches the mineral owner
• Producing Permian Basin interests trade at 40–60x monthly royalties; Fort Worth Basin Barnett Shale interests trade at 30–45x; buyers apply 10–15% discount rates to Permian interests and 15–20%+ to Barnett Shale gas interests

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Frequently Asked Questions

What is the difference between net mineral acres and gross acres?

Gross acres is the total surface area of the tract. Net mineral acres (NMA) is the gross acreage multiplied by the fractional mineral ownership. If a 640-acre tract has 10 mineral owners each holding an undivided 1/10 interest, each owner has 64 NMA. The gross acreage of the tract does not change — only the fractional ownership determines NMA. Buyers should always confirm NMA through a title opinion, not through the seller's summary, because prior reservations in the deed chain can reduce actual NMA below the stated figure.

What is a term mineral interest and how do I know if one has expired?

A term mineral interest is a mineral interest limited in duration — it expires at the end of a specified period unless production is occurring. The creating deed specifies the term and any savings clause. To determine whether a term mineral interest is still valid, a title examiner must locate the creating deed, calculate the remaining term, and confirm whether production was established before expiration. In Comanche and Eastland Counties, term mineral interests are common in deed chains from the mid-20th century. An expired term mineral interest has no value — the mineral estate reverts to the surface owner or the grantor's heirs.

How does the royalty fraction in the lease affect the value of an acreage interest?

The royalty fraction in the lease directly determines how much of gross production revenue flows to the mineral owner. A 1/4 (25%) royalty lease generates twice the royalty income of a 1/8 (12.5%) royalty lease on the same production. Fort Worth Basin Barnett Shale leases from the early 2000s — many at 1/8 to 3/16 royalty and lacking "free of cost" language — are significantly less valuable than modern Permian Basin leases at 1/4 or higher. Buyers acquire the interest subject to the existing lease and cannot renegotiate the royalty fraction until the lease expires.

What is the difference between an ORRI and a mineral interest?

An overriding royalty interest (ORRI) is a royalty interest carved out of the working interest — it is not a mineral interest and does not survive lease expiration. When the current lease terminates, the ORRI expires with it. A mineral interest survives lease expiration and can be re-leased. ORRI vs. mineral interest confusion is the most common Fort Worth Basin due diligence mistake I encounter. The creating deed is the authoritative source — always confirm whether the interest being acquired is a mineral interest or an ORRI before closing.

How does Texas State Royalties source acreage interests for buyers?

Texas State Royalties facilitates direct mineral-interest acquisitions for buyers who have clear criteria and the ability to close. We source opportunities through established industry relationships, verify 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 and do not represent sellers. Start Your Buyer Search or review our acquisition services to learn more.

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For a complete guide to evaluating a mineral interest before you close, see: How to Evaluate a Mineral Interest Before You Buy.

For a guide to the deed conveyance process and what a valid Texas mineral deed must contain, see: What Is Deed Conveyance?.

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About the Author

Richard Partin is the Managing Member of Texas State Royalties, a Fort Worth-based, buyer-first firm that sources producing oil and gas mineral interests through established industry relationships. He holds a degree from the University of Texas at Arlington and has years of hands-on experience in oil and gas acreage interests, working interests, and capital formation across active Texas producing regions.

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 facilitates mineral-interest acquisitions and works exclusively with buyers. 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. Buyers should consult qualified legal, tax, and financial advisors before making any acquisition decision.