Terms of the Trade
Plain-English definitions for the terms you'll run into when you sell mineral rights or royalty interests.
A chronological summary of every recorded instrument affecting a tract — patents, deeds, leases, assignments, releases, mortgages — back to the original sovereign grant. Abstracts are the input to a title opinion and are essential when the chain of mineral title is unclear.
See also: Title Opinion, Curative Requirement
A budget document an operator sends to working interest owners listing the estimated cost of a planned well. Each working interest owner signs (consents) or declines (non-consents); non-consenting owners typically lose their share of the well’s production until a multiple-of-cost penalty is recovered.
See also: Working Interest (WI), Joint Operating Agreement (JOA)
A sworn statement by a disinterested witness identifying the heirs of a deceased mineral owner when a formal probate has not been completed. Most states accept a properly executed and recorded affidavit of heirship after a defined waiting period (typically 5 years) as sufficient for division-order purposes.
See also: Curative Requirement, Royalty in Suspense
Mineral rights held more than one year qualify for long-term capital gains treatment on sale — generally 0%, 15%, or 20% federal depending on income, plus state income tax. The basis used is acquisition cost (or stepped-up FMV for inherited interests) plus any depletion adjustments.
See also: Stepped-Up Basis, Depletion Allowance, Section 1031 Exchange
A working interest whose share of drilling and completion costs is paid by another working interest owner up to a defined event — typically payout (recovery of costs from production). After the carry ends, the carried owner begins paying its share of ongoing costs.
See also: Working Interest (WI), Farmout Agreement
A lease clause that lets the lessee keep undeveloped acreage past the primary term as long as drilling operations continue at a defined cadence — typically a new well spudded within a fixed window after the previous one. Common on large modern leases targeting horizontal development.
See also: Oil and Gas Lease, Pugh Clause, Spudded
A royalty interest that bears no share of post-production costs — gathering, compression, processing, transportation. Cost-free language must be explicit in the lease or deed; absent that, courts in most states allow operators to deduct a reasonable share.
See also: Royalty Interest (RI), Post-Production Costs, Marketable Product Rule
A defect in title flagged by an attorney that must be cured before the operator will pay royalties — missing affidavits of heirship, unrecorded deeds, gaps in the chain, or unreleased prior leases. Operators often hold royalty in suspense until curative is complete.
See also: Title Opinion, Affidavit of Heirship, Royalty in Suspense
An owner’s share in a well expressed as a decimal — for example, 0.00781250 for a 1/128 royalty interest. The decimal interest combines acreage owned, royalty fraction, and the unit’s producing interest into a single number used on the division order and check stubs.
See also: Division Order, Net Revenue Interest (NRI), Net Mineral Acres (NMA)
A periodic payment (typically annual) the lessee makes during the primary term of an unproduced lease to keep it in force without drilling. Most modern leases are paid-up — meaning the bonus covers the entire primary term and no separate delay rentals are due.
See also: Oil and Gas Lease, Lease Bonus
A federal income tax deduction recognizing the gradual exhaustion of a mineral resource. Royalty owners typically use percentage depletion at 15% of gross income, capped at 100% of net income from the property. Depletion is deductible against royalty income each year it is received.
See also: Capital Gains (Mineral Rights), Royalty Interest (RI)
A lease provision (or a deed reservation) that limits the depth interval covered. A depth-severed lease may cover only formations above 8,000 feet, leaving deeper rights with the mineral owner — important in stacked basins where multiple plays exist at different depths.
See also: Pugh Clause, Mineral Rights
Common in: Texas, Oklahoma, and New Mexico
A document from the operator that lists every owner entitled to revenue from a well and the decimal interest each one receives. You sign it to confirm your share before the operator starts sending royalty checks.
See also: Royalty Interest (RI), Net Revenue Interest (NRI), Decimal Interest
The right to negotiate and execute oil and gas leases on behalf of a mineral interest. Executive rights can be split off from the underlying mineral interest, so an NPRI holder may receive royalties without holding executive rights, and another party may execute leases without owning royalties.
See also: Mineral Interest (MI), Non-Participating Royalty Interest (NPRI), Oil and Gas Lease
An agreement under which a working interest owner (the farmor) lets another party (the farmee) earn an interest in the lease by drilling a well at the farmee’s expense. Farmouts typically reserve an ORRI to the farmor and convert to a working interest at payout.
See also: Working Interest (WI), Overriding Royalty Interest (ORRI), Carried Interest, Joint Operating Agreement (JOA)
A lease clause excusing the lessee from performance obligations during events beyond their control — hurricanes, regulatory shutdowns, pipeline failures, wars. Force majeure can extend the primary term but generally does not override an explicit production requirement in the habendum clause.
See also: Oil and Gas Lease, Habendum Clause
A statutory mechanism by which a state regulator can include uncommitted mineral owners in a drilling unit over their objection, on terms set by the regulator. Oklahoma’s pooling regime through the Corporation Commission is the most aggressive in the country; North Dakota and New Mexico use forced pooling routinely.
See also: Pooling and Unitization, Spacing Unit / Drilling Unit
Common in: Oklahoma, North Dakota, and New Mexico
The lease clause that defines its duration — a primary term (a fixed number of years) plus a secondary term that lasts as long as oil or gas is produced in paying quantities. The habendum clause is what creates "held by production" status.
See also: Oil and Gas Lease, Held by Production (HBP), Paying Quantities
A lease status that stays in effect as long as the well continues producing in paying quantities, even after the original primary term has expired. HBP acreage is common in mature basins and typically commands a higher valuation than expired leases.
See also: Oil and Gas Lease, Paying Quantities
Common in: Texas, Oklahoma, New Mexico, and North Dakota
Duties read into every oil and gas lease by courts even when not written: to develop reasonably, to protect against drainage, to market diligently, and to operate prudently. The marketing covenant is the most-litigated — it underpins disputes over post-production cost deductions.
See also: Oil and Gas Lease, Post-Production Costs, Marketable Product Rule
The contract among working interest owners in a unit that governs day-to-day operations: who is the operator, how AFEs are approved, how costs are allocated, what happens to non-consenting owners. Most US JOAs follow a 1989 or 1982 AAPL form with negotiated exhibits.
See also: Working Interest (WI), AFE (Authorization for Expenditure), Farmout Agreement
A Pennsylvania Supreme Court doctrine (Kilmer v. Elexco) that allows operators to deduct post-production costs from royalty payments under the "net-back" method even on legacy 1/8 leases — opposite the Tawney result in West Virginia. Kilmer is one of the most-litigated points in PA Marcellus royalty disputes.
See also: Post-Production Costs, Marketable Product Rule, Tawney Rule
Common in: Pennsylvania
A one-time, up-front cash payment from a lessee to the mineral owner in exchange for signing an oil and gas lease. It is separate from and in addition to any future royalty payments.
See also: Oil and Gas Lease, Royalty Interest (RI), Delay Rental
A judicial doctrine in some states (Oklahoma, Kansas, West Virginia) that requires the lessee to bear all costs of making the produced gas a "marketable product" — meaning the operator cannot deduct gathering, compression, or processing from royalty until the gas is marketable. Texas, by contrast, allows post-production deductions absent express lease language to the contrary.
See also: Post-Production Costs, Cost-Free Royalty, Implied Covenants
Common in: Oklahoma, Kansas, West Virginia, and Pennsylvania
A land-description system using physical landmarks and compass bearings ("thence north 47 degrees east 230 feet to a fence post") rather than the rectangular PLSS grid. Texas — never part of the federal public domain — uses metes-and-bounds inherited from Spanish and Republic-era grants.
See also: Section, Township, and Range
Common in: Texas
An ownership interest in the oil, gas, and other minerals beneath a tract of land. A mineral interest owner has the right to explore, develop, and lease the minerals, and to receive bonus, delay rentals, and royalties under any lease.
See also: Mineral Rights, Royalty Interest (RI), Working Interest (WI), Executive Rights
The legal rights to the minerals (oil, gas, coal, etc.) beneath a parcel of land. Mineral rights are a type of real property that can be owned, sold, leased, and inherited separately from the surface land above them.
See also: Mineral Interest (MI), Severed Mineral Rights
The mineral owner’s share of a tract expressed in acres. For example, owning a 25% undivided interest in a 160-acre tract equals 40 net mineral acres. NMA is the standard unit used to value and price mineral transactions.
See also: Mineral Interest (MI), Decimal Interest
An owner’s share of the revenue from a well after royalties and other burdens have been deducted. For a royalty owner, NRI equals their decimal interest in the well as shown on the division order.
See also: Royalty Interest (RI), Division Order, Working Interest (WI), Decimal Interest
A royalty interest carved out of the mineral estate that entitles the holder to a share of production revenue but not to bonus, delay rentals, or the right to lease. NPRIs are often created by reservation in a deed or by a royalty deed.
See also: Royalty Interest (RI), Mineral Interest (MI)
The contract between a mineral owner (lessor) and an operator (lessee) granting the operator the right to drill and produce oil and gas in exchange for a bonus payment and a royalty on production. A typical lease has a primary term and is then held by production.
See also: Lease Bonus, Held by Production (HBP), Royalty Interest (RI), Habendum Clause
A royalty interest carved out of a working interest, not the mineral estate. An ORRI lasts only as long as the underlying lease and terminates when the lease expires.
See also: Royalty Interest (RI), Working Interest (WI), Oil and Gas Lease
Common in: Texas, Oklahoma, and New Mexico
The threshold of production required to keep a lease alive past its primary term. Most state courts define paying quantities as production whose revenue exceeds operating costs over a reasonable period — a low bar, but courts have invalidated leases held by economically marginal wells.
See also: Held by Production (HBP), Oil and Gas Lease
A well permanently sealed with cement plugs at the end of its life, with surface equipment removed and the location reclaimed. P&A obligations typically fall on the last working interest owner of record; some states bond against P&A liability to prevent orphan wells.
See also: Working Interest (WI), Workover / Recompletion
The combining of separately owned mineral tracts into a single drilling or production unit, so that a horizontal well or large-scale development can share production proceeds proportionally among all owners in the unit. Pooling can be voluntary or compulsory depending on state law.
See also: Oil and Gas Lease, Forced Pooling (Compulsory Pooling), Spacing Unit / Drilling Unit
Common in: Oklahoma, North Dakota, and New Mexico
Costs incurred between the wellhead and the point of sale — gathering, compression, dehydration, processing, transportation. Whether and how much an operator can deduct from royalty owners varies by state and by the marketable-product rule the state has adopted.
See also: Royalty Interest (RI), Cost-Free Royalty, Marketable Product Rule, Implied Covenants
Common in: Pennsylvania, West Virginia, Oklahoma, and Kansas
A lease provision that releases the unpooled or undeveloped portions of leased acreage at the end of the primary term, so the operator cannot hold thousands of acres with a single producing well in one corner. Vertical Pugh clauses also release rights below a defined depth.
See also: Oil and Gas Lease, Held by Production (HBP), Depth Severance / Depth Clause
A lawsuit asking a court to declare definitive ownership of a parcel and clear up clouded title. Used when affidavits and curative documents cannot resolve the dispute — for example, when an unknown heir or a stale mineral reservation is in the chain.
See also: Title Opinion, Curative Requirement, Affidavit of Heirship
A lease clause that limits the amount of acreage held by each producing well to a defined "retained" tract — usually a spacing unit or a contractual area such as 80, 160, or 320 acres around the wellbore. Acreage outside retained tracts is released back to the mineral owner.
See also: Pugh Clause, Oil and Gas Lease, Spacing Unit / Drilling Unit
The fraction of production a royalty owner receives under a lease — historically 1/8 (12.5%), now commonly 1/5 (20%) or 1/4 (25%) on competitive modern leases in active basins. The royalty fraction is set in the lease and applies to the gross production attributable to the lessor’s acreage.
See also: Royalty Interest (RI), Oil and Gas Lease, Net Revenue Interest (NRI)
Royalty held by an operator and not paid out to the owner of record because of unresolved title questions, an unsigned division order, a probate not yet completed, or a missing payee mailing address. Suspense balances accrue to the rightful owner once the title or paperwork issue is cured.
See also: Curative Requirement, Division Order, Title Opinion
The right to receive a fractional share of production, or the revenue from production, free of the costs of drilling and operating the well. The classic 1/8 lease royalty is the most common example.
See also: Mineral Interest (MI), Non-Participating Royalty Interest (NPRI), Overriding Royalty Interest (ORRI), Net Revenue Interest (NRI)
A tax-deferred exchange of like-kind real property under IRC §1031. Mineral interests qualify as like-kind to other real property, so a mineral owner can sell one tract and roll the proceeds into another (or other qualifying real estate) without triggering current capital gains tax — provided the strict 45/180 day deadlines and qualified-intermediary rules are followed.
See also: Capital Gains (Mineral Rights), Stepped-Up Basis
The Public Land Survey System (PLSS) grid used across most of the western and central United States to describe land. A standard section is one square mile (640 acres); 36 sections make a township. Mineral deeds and leases almost always use this description.
Common in: Oklahoma, New Mexico, North Dakota, Colorado, Wyoming, Kansas, Montana, and Utah
Mineral rights that have been legally separated from the surface estate, so the mineral owner and the surface owner are different parties. Once severed, the mineral estate is generally the dominant estate and carries implied rights to use the surface reasonably to develop the minerals.
See also: Mineral Rights, Mineral Interest (MI), Surface Use Agreement (SUA)
A small annual payment a lessee can make to keep a lease alive when a well capable of producing in paying quantities is shut in (idle), typically for lack of a market or pipeline. Shut-in royalty clauses prevent the lease from terminating during temporary curtailments.
See also: Oil and Gas Lease, Paying Quantities, Held by Production (HBP)
The acreage assigned to a single well by a state regulator — historically 40, 80, 160, or 320 acres for vertical wells, now commonly 640 or 1,280 acres for horizontal wells in unconventional plays. A unit’s production is shared by all owners in the unit on an acreage-weighted basis.
See also: Pooling and Unitization, Forced Pooling (Compulsory Pooling), Retained Acreage Clause
The moment a drilling rig first turns to the right and breaks ground — the formal start of drilling a well. State regulators track spud dates as the trigger for permit-expiry, lease-extension, and bonding requirements.
See also: Oil and Gas Lease, Continuous Drilling Clause
For inherited assets, the IRS resets the cost basis to the asset’s fair market value on the date of the decedent’s death. For inherited mineral rights, this typically eliminates the embedded capital gain that accumulated during the decedent’s lifetime — a critical planning point for sales after probate.
See also: Capital Gains (Mineral Rights), Depletion Allowance
A negotiated agreement between an operator and a surface owner setting terms for surface activities — pad locations, road routing, water sourcing, surface-damage payments, reclamation. In split-estate states, a written SUA is the surface owner’s primary leverage point.
See also: Severed Mineral Rights
Common in: Wyoming, Colorado, and New Mexico
A West Virginia Supreme Court doctrine (Estate of Tawney v. Columbia Natural Resources) requiring that lease language allowing post-production-cost deductions be specific and unambiguous. Generic "market value at the wellhead" language is insufficient under Tawney; royalty owners receive a gross calculation absent express deduction terms.
See also: Post-Production Costs, Marketable Product Rule, Cost-Free Royalty
Common in: West Virginia
A written legal opinion by an oil and gas attorney describing who owns the surface, mineral, and royalty interests in a tract, and what curative work is required. Operators rely on title opinions to issue division orders and pay royalties.
See also: Abstract of Title, Division Order, Curative Requirement
An operating interest in an oil and gas lease that bears its proportionate share of the costs of drilling, completing, and operating the well. Working interest owners receive revenue after royalties and other burdens are paid.
See also: Royalty Interest (RI), Net Revenue Interest (NRI), Oil and Gas Lease, Carried Interest
Operations on an existing well to restore or improve production: re-perforating, re-fracking, swabbing, replacing tubing, or completing a different formation up the wellbore. Workovers are smaller in scope than drilling a new well but can extend a well’s economic life by years.
See also: Working Interest (WI), Plugged and Abandoned (P&A)