Buckhead Energy buys Texas royalty interests, ORRIs, and NPRIs with our own capital — from Permian Basin checks to long-lived Barnett and East Texas gas royalties. Free written offer, zero fees or commissions, closing in 30–45 days.
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Get Your Free Texas Royalty OfferQuick Answer To sell oil and gas royalties in Texas: gather your division orders and recent check stubs, request a written offer from a direct buyer, review the purchase and sale agreement, and close by notarized conveyance recorded in the county where the minerals sit. Texas royalties carry two state-specific wrinkles worth knowing before you sell — severance tax withheld at the wellhead, and county ad valorem tax assessed on producing interests. Buckhead Energy is a direct Texas royalty buyer since 2007, and makes free written offers with no fees or commissions.
There is no single "best" royalty buyer for every Texas owner — but there are four filters that separate a serious buyer from an intermediary. First, is the buyer using its own capital? If closing is contingent on the buyer finding a third party, you are working with a broker and the offer can move. Second, will they put the offer and its reasoning in writing? A buyer who models your wells should be able to show you how the number was built. Third, who pays the title and closing costs? Fees and commissions come straight out of your proceeds. Fourth, do they actually buy in your county? A buyer active in the Permian may have no appetite for a Panhandle or East Texas gas royalty. Buckhead Energy is a direct buyer, buys with its own funds, pays the title costs, and works every producing county in Texas.
The classic royalty under a lease on your Texas minerals — monthly checks from operator production, free of drilling and operating costs.
Carved out of the working interest — common for landmen, geologists, and dealmakers. ORRIs expire with their lease, which makes timing a real consideration. ORRI guide →
Royalty without executive rights or bonus — often inherited and misunderstood. Fully sellable. NPRI guide →
Producing or recently shut-in, whole or fractional, one well or many counties — including inherited interests still in an estate (we handle heirship).
In almost every state, your oil & gas royalty is set by your lease — not by statute. There is no government-set royalty rate for privately negotiated leases.
Texas has no broad forced pooling — the Mineral Interest Pooling Act is narrow, rarely used, and sets no statutory royalty. An unleased owner's royalty is 100% whatever a lease negotiates, or they simply stay unleased and unbound.
Source: Tex. Nat. Res. Code ch. 102 (MIPA)
Typical negotiated lease royalty (market convention, not law): Across the U.S., negotiated oil & gas leases have historically run from 1/8 (12.5%) at the low end to 1/4 (25%) in the most competitive plays, with 3/16 (18.75%) and 1/5 (20%) common in active basins. Your actual rate depends on the play, the operator, the competition for your acreage, and when you signed — not on any state rate.
Texas severance ("production") tax is withheld before your royalty check is cut, which is why your gross and net differ on the stub. The published rates:
Source: Texas Comptroller — Crude Oil Production Tax
Reduced rates and exemptions exist (for example, enhanced oil recovery and certain inactive wells), and condensate is taxed at the oil rate. Rates change by legislative action. Confirm your own position with a CPA — this is published reference, not tax advice.
Texas is one of the states that taxes producing mineral interests as property. Each county appraisal district assigns a mineral account with your name, decimal interest, and an appraised value. That has two consequences when you sell: the appraisal roll is a fast way to confirm what you own, and the annual tax bill is a real carrying cost on interests that produce very little.
Unlike North Dakota, Kansas, and Ohio, Texas has no use-it-or-lose-it statute that lapses an unused mineral or royalty interest to the surface owner. A Texas royalty does not expire from inactivity. Adverse possession and abandoned-lease questions are separate matters — but you are not on a dormancy clock.
Most states use section-township-range. Texas uses the original survey name and abstract number — "A-123, John H. Smith Survey" — which is why a Texas royalty conveyance reads differently from an Oklahoma one, and why matching your tract to the right abstract is the step owners most often get wrong.
The RRC — not a "railroad" agency in any practical sense today — regulates oil and gas in Texas. Its public records tie leases, permits, wells, and operators to your tract, and are the corroborating source we check on every Texas evaluation.
West Texas — the most actively drilled royalty base in the country, spanning the Midland and Delaware sub-basins.
The eastern Permian sub-basin — stacked Wolfcamp and Spraberry benches under heavy horizontal development.
The western Permian sub-basin reaching into New Mexico — deeper, gassier, and still adding drilling locations.
South Texas oil, condensate, and gas windows — mature horizontal development with refracs extending well life.
East Texas and North Louisiana dry gas — long-lived royalties highly levered to Henry Hub.
We also buy Barnett Shale royalties around Fort Worth (our own backyard), Austin Chalk, Granite Wash and Panhandle interests, and legacy East and West Texas production — including small checks from long-lived stripper wells.
Active Texas royalty counties include:
All Texas counties we buy in → · Monthly Texas drilling activity report →
Permian decline is front-loaded: Modern horizontal Texas wells pay the majority of their royalties in the first few years. A check that looks strong today is not a flat annuity — selling near the peak captures value the decline curve otherwise takes back.
Ad valorem tax on thin interests: A county mineral account that produces a few hundred dollars a year can still generate an annual tax bill and a return to file. For scattered or inherited Texas interests, the administrative drag often outruns the income.
Fractions split across heirs: Texas interests divide with every generation. By the third or fourth, a single tract can carry dozens of owners each holding a small decimal — and a sale is frequently simpler than perpetual co-ownership.
Gas-weighted royalties ride Henry Hub: East Texas and Barnett royalties track gas prices closely. Owners who want out of that volatility can convert the remaining stream into a fixed number today.
Before you sell — or decide not to — read your own income stream like a buyer would: your royalty statement line by line, the full royalty calculation chain, and your trend over the last year. Run your own numbers with our royalty calculator, ground-truth prices against live WTI & Henry Hub benchmarks, and see who operates around you on the top Texas operators leaderboard. The more you know, the better our conversation.
Gather your division orders, three to twelve months of royalty check stubs, and your lease if you have it. Request a written offer from a direct buyer, review the purchase and sale agreement, then close by notarized conveyance recorded in the county where the minerals sit. Buckhead Energy handles and pays for the Texas title work and typically closes within 30 to 45 days.
Direct buyers purchasing with their own capital to hold, institutional royalty funds, and broker intermediaries who resell the interest. Buckhead Energy is a direct buyer working every producing Texas county — Permian, Eagle Ford, Barnett, Haynesville, Panhandle, and legacy East and West Texas production. The filter question for any buyer: are they buying with their own funds, and is closing contingent on them finding someone else?
A royalty sale is generally treated as a sale of a capital asset rather than as ordinary royalty income, and Texas has no state personal income tax — but the specifics depend on your basis, holding period, and how the interest was acquired, particularly for inherited interests. Talk to a CPA before closing. Separately, Texas severance tax is withheld from production before your checks are issued, and county ad valorem tax is assessed on producing interests.
Texas has no dormant-mineral statute, so a Texas royalty interest does not lapse to the surface owner from inactivity — unlike North Dakota, Kansas, or Ohio. Your interest can still be affected by unclaimed-property escheat if checks go uncashed and the operator cannot locate you, and by lease termination provisions, but there is no dormancy deadline on the ownership itself.
Value follows your actual income and its expected path: your decimal interest, each well's production and decline profile, remaining undrilled locations in the unit, current oil and gas prices, and any post-production deduction language in the lease. There is no per-acre shortcut for a producing royalty. A written offer computed from your check stubs and Railroad Commission records is the realistic answer, and Buckhead provides one free with the reasoning explained.
Yes. Partial conveyances are routine — many owners sell a fraction for liquidity and keep the rest. The deed simply describes the portion conveyed.
A royalty interest is the income stream only; mineral rights include the underlying ownership with leasing (executive) rights. Both are sellable. ORRIs (carved from leases, expiring with them) and NPRIs (royalty without bonus or executive rights) are royalty-type interests Buckhead purchases regularly.
Often, yes. Small persistent checks — especially from long-lived stripper wells — carry real present value, and administrative burden frequently outweighs modest income for scattered or inherited interests. A written offer prices the whole remaining stream at once.
This page is educational and is not legal, tax, or financial advice. Statutory rates are quoted from the linked issuing agency as of 2026-07-21 and can change by legislative action. Consult a qualified attorney and CPA about your own interest before selling.
Sell royalties — national overview · Compare Texas to another state · Texas mineral rights · Sell minerals in Texas
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