Buckhead Energy buys Utah royalty interests, ORRIs, and NPRIs with our own capital — Uinta Basin waxy crude, Paradox Basin oil, and central Utah thrust belt production. Free written offer, zero fees or commissions, closing in 30–45 days.
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Get Your Free Utah Royalty OfferQuick Answer To sell oil and gas royalties in Utah: gather your division orders and recent check stubs, request a written offer from a direct buyer, and close by notarized conveyance recorded in the county where the minerals sit. Utah's severance tax is price-tiered — 3% on the first tranche of per-unit value and 5% above it — and applies to royalty and working interests alike. Utah has no dormant mineral statute; minerals are expressly carved out of the state's marketable title act. The Utah-specific question to settle first is whether your tract is fee, federal, or tribal, because that changes both the royalty and the tax.
There is no single "best" royalty buyer for every Utah owner, but four filters separate a serious buyer from an intermediary. Is the buyer using its own capital? Will they put the offer and its reasoning in writing? Who pays title and closing costs? And does the buyer price Uinta crude correctly? Uinta production is waxy, yellow-wax crude with genuinely different takeaway and realized pricing from a Permian barrel — a buyer applying a generic WTI assumption to a Uinta royalty is not pricing your interest. Buckhead Energy is a direct buyer, buys with its own funds, and pays the title costs.
The classic royalty under a lease on your Utah 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.
You are guaranteed a royalty, but it is not a fixed fraction — since 2014 (SB 213) the statute pegs it to the drilling unit's average weighted landowner royalty, superseding the old 1/8 standard.
Source: Utah Code § 40-6-6.5(6)
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.
The tier applies to per-unit value, so at any realistic modern price the first tranche is taxed at 3% and everything above it at 5%, blending to slightly under 5%:
Source: Utah Code § 59-5-102(4)(a)
Source: Utah Code § 59-5-102(4)(b)
Source: Utah Code § 59-5-102(4)(c)
Unlike Montana, the rate does not differ between working and royalty interests — the statute imposes it on every interest owner in proportion. Substantial exclusions narrow the base: interests of the United States, the State of Utah, and Indian tribes in production from land under federal jurisdiction; stripper-well production; the first twelve months of a wildcat well and first six months of a development well started after 1990; and a 50% rate reduction on enhanced-recovery incremental production. Confirm your own position with a CPA — this is published reference, not tax advice.
All Utah oil and gas production properties are valued annually by the Utah State Tax Commission's Centrally Assessed Division using a discounted-cash-flow method, then apportioned to counties by situs, with each county treasurer billing and collecting. Royalty is not deducted in arriving at the assessed value, so the full producing property interest — royalty included — sits inside the assessment.
Severed Utah minerals do not lapse for non-use. Utah's Marketable Record Title Act is the only state statute that extinguishes stale interests, and it expressly states it may not be applied to extinguish any interest in minerals or the rights exercisable in connection with them. The real Utah risk to severed mineral title is not dormancy but tax title — where a surface owner fails to pay and the county sells the property — though Utah courts have held a tax sale void as to severed minerals where the mineral owner received no constitutionally adequate notice.
Utah is a rectangular-survey state. Nearly all of Utah is surveyed off the Salt Lake Base and Meridian, but a portion of the Uinta Basin in the northeast runs off the Uintah Special Base and Meridian. That is a genuine trap: a section-township-range description in Duchesne or Uintah County must state which meridian it references, or it can describe the wrong ground entirely.
DOGM permits Utah wells and publishes the production records we check on every Utah evaluation.
Northeast Utah and the dominant producer — Tertiary Wasatch and Green River formations, anchored by Altamont-Bluebell. The overwhelming majority of Utah production is in Duchesne and Uintah counties.
The Uinta Basin's principal unconventional target. Uinta crude is waxy and yellow-wax, which materially affects realized pricing and takeaway.
Southeastern Utah, chiefly San Juan County — Greater Aneth field plus the Cane Creek Shale and related black shales.
The newest conventional province, opened by the Covenant field discovery in Sevier and Sanpete counties.
Active Utah royalty counties include:
All Utah counties we buy in → · Monthly Utah drilling activity report →
Waxy crude prices differently: Uinta Basin barrels carry their own takeaway constraints and realized-price behavior. That basis risk is real and is one of the things a lump sum removes.
Federal and tribal ownership is pervasive: The Uinta Basin carries very large federal and Ute Indian Tribe mineral ownership, which complicates leasing and administration for a small fee owner.
The meridian trap: Uinta Basin descriptions run off two different meridians. Owners are sometimes uncertain what they actually hold — a title question worth resolving whether you sell or not.
Fractions split across heirs: Long-held Utah family minerals have divided across generations into small decimals.
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 Utah operators leaderboard. The more you know, the better our conversation.
Gather your division orders, three to twelve months of 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 Utah title work and typically closes within 30 to 45 days.
Utah tiers by per-unit value: 3% on the first $13 per barrel of oil and 5% above that, and 3% on the first $1.50 per MCF of gas and 5% above that, with natural gas liquids at 4%. At realistic modern prices the blend lands slightly under 5%. Unlike Montana, the rate is the same for royalty and working interests. Several exclusions narrow the base, including stripper wells and federal or tribal interests.
No. Utah has no dormant mineral act, and its Marketable Record Title Act expressly states it cannot be applied to extinguish mineral interests. The genuine Utah risk is tax title — a county tax sale following a surface owner's non-payment — though Utah courts have held such a sale void as to severed minerals where the mineral owner got no adequate notice.
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.
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