Buckhead Energy buys California royalty interests, ORRIs, and NPRIs with our own capital — San Joaquin heavy oil, Los Angeles and Ventura basin production, Sacramento Basin gas. Free written offer, zero fees or commissions, closing in 30–45 days.
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Get Your Free California Royalty OfferQuick Answer To sell oil and gas royalties in California: 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. California has no statewide severance tax — only a small annual regulatory assessment levied on operators — but the county assessor can separately assess and tax your mineral interest as real property. That matters twice over, because under California's dormant mineral statute, letting a separate assessment go unpaid is one of three legs of the test that can cost you the interest entirely.
There is no single "best" royalty buyer for every California 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 can the buyer read a rancho description? Coastal and Southern California title routinely straddles the rectangular survey and Spanish and Mexican land grants described by patent name and recorded map. A buyer unfamiliar with both systems will discount for uncertainty. Buckhead Energy is a direct buyer, buys with its own funds, and pays the title costs.
The classic royalty under a lease on your California 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.
California can force-pool an owner only after a spacing order and a failed 60-day voluntary window, to protect correlative rights — but no statute guarantees any minimum royalty. Pooling is rare; most development is voluntary.
Source: 14 CCR § 1721.8 (Pub. Res. Code §§ 3600 et seq.)
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.
California levies no statewide severance tax on oil and gas production. What it has is a small annual Oil and Gas Assessment charged to operators, set each June by dividing the regulator's budget by prior-year assessable production and applied per barrel of oil and per 10,000 cubic feet of gas. Because it funds the regulator and is billed to producers, it does not behave like a severance tax deducted from a royalty check.
The per-barrel rate is reset annually and has risen substantially over time, so any specific figure should be checked against the current year. Confirm your own position with a CPA — this is published reference, not tax advice.
California counties administer ad valorem property taxes on producing oil and gas interests. Beyond the ordinary reason to pay a tax bill, there is a title reason specific to California: an unpaid separate assessment on a mineral right is one of the three conditions that together make an interest "dormant" and exposed to termination.
A surface owner may bring an action to terminate a mineral right that is dormant, and a right is dormant only if <strong>all three</strong> conditions held for the twenty years immediately preceding the action: no production or operations affecting the minerals on the property or on pooled or unitized property; no separate property tax assessment of the mineral right, or if assessed, no taxes paid; and no recorded instrument creating, reserving, transferring, or evidencing the right. Because all three legs are required, paying an assessment or recording an instrument defeats it. An owner may also record a notice of intent to preserve at any time — and uniquely, that notice may refer generally to any or all mineral rights the claimant holds anywhere in the county, making it cheap, broad insurance.
Statute: Cal. Civ. Code §§ 883.210–883.270
California is a public-land state surveyed under three principal meridians: Mount Diablo across the north and center, San Bernardino in the south, and Humboldt in the far northwest. But land confirmed to Spanish and Mexican grantees before statehood was never subdivided into sections, and those ranchos are described by patent name, metes and bounds, and recorded maps. Coastal and Southern California mineral descriptions frequently read "Rancho ___, as per map recorded in Book __ of Maps" rather than a section call, and title work in Los Angeles, Ventura, Santa Barbara, Orange, and Monterey routinely straddles both systems.
CalGEM — renamed from DOGGR, so older division orders and title work still say "DOGGR" — permits California wells and publishes the production records we check on every California evaluation.
Overwhelmingly the dominant producing basin — Kern County alone produces more than the rest of the state combined, with heavy-oil thermal recovery at Midway-Sunset, Kern River, Belridge, and Elk Hills.
Very high oil-in-place per acre at Wilmington, Inglewood, and Long Beach — but under dense urban development, so surface access and municipal drilling ordinances drive value.
Structurally complex, steeply dipping folded reservoirs, and one of the state's larger gas producers.
California's dry-gas province — royalty economics in Colusa and Glenn are pure gas, unlike the rest of the state.
We also buy Santa Maria Basin and Salinas Basin interests — heavy, sour crude in Santa Barbara, San Luis Obispo, and Monterey counties.
Active California royalty counties include:
All California counties we buy in → · Monthly California drilling activity report →
Regulatory and permitting friction: California permitting is among the most constrained in the country, and urban-basin production faces municipal ordinances on top of state rules. That directly affects whether and when your tract sees new activity.
The three-legged dormancy test: A California mineral right can be terminated by court action if all three dormancy conditions hold for twenty years. Recording a notice of intent to preserve — which can cover every interest you own in the county — defeats it cheaply.
Heavy oil economics: San Joaquin thermal production carries high operating costs, so realized royalty behaves differently from a light-oil basin.
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 California operators leaderboard. The more you know, the better our conversation.
No statewide severance tax. California instead levies a small annual Oil and Gas Assessment on operators, set each June by dividing the regulator's budget by prior-year assessable production, applied per barrel of oil and per 10,000 cubic feet of gas. Because it funds the regulator and is billed to producers, it does not behave like a severance tax deducted from your royalty check. County ad valorem property tax is a separate matter and does apply.
Potentially, but only through a court action and only if all three statutory conditions hold for twenty years: no production or operations, no separate property tax assessment or no taxes paid on it, and no recorded instrument evidencing the right. Because all three legs are required, paying an assessment or recording an instrument defeats the claim. You can also record a notice of intent to preserve, which uniquely may cover every mineral right you own anywhere in the county.
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 California title work and typically closes within 30 to 45 days.
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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