Minerals, oil and gas
Oil and gas royalty interests
The phrase 'oil and gas interest' covers instruments that behave nothing alike. One is free of cost and lasts as long as the minerals do. One dies with the lease it was carved from. One pays only after costs. And one makes you a part-owner of the well, with the bills and the liability that come with it.
Start here if the word royalty is all you know: somebody uses something you own, and a slice of what they earn from that use is sent to you. Everything on this page is a description of who counts the uses, who writes the cheque, when it arrives and what makes it shrink. What would mislead: assuming one royalty is like another. The rules below apply to this type only, and the money can arrive months after the use that earned it.
Five interests that are not the same thing
They can pay identical amounts this month and have completely different lives.
- Royalty interest (RI)
- Created by the lease out of the mineral estate. Entitled to a fraction of production free of the cost of drilling and operating. It survives as long as the mineral ownership does — a new lease creates a new royalty when the old one expires.
- Overriding royalty interest (ORRI)
- Carved out of the working interest rather than the minerals. Also cost-free, but it is a creature of a specific lease and terminates when that lease terminates. Two interests can pay identically today and have completely different lives, and this is the difference.
- Non-participating royalty interest (NPRI)
- A royalty carved out of the mineral estate whose owner does not share in lease bonus or delay rentals and, depending on how it was created, has no executive right to lease. It collects on production and nothing else, with no vote on whether production happens.
- Net profits interest (NPI)
- Carved from the working interest and paid out of profits after defined costs. It bears cost indirectly, which means it can pay nothing in a period when the property runs at a loss, and where the conveyance escalates the chargeable cost it can be permanently out of the money while wells still produce. Several listed royalty trusts hold this, not a pure royalty.
- Working interest (WI)
- The operating interest under the lease. It receives revenue after royalties and pays its share of drilling, completion and operating costs, plus plugging and environmental liability. It is generally treated as an active trade or business for US tax purposes — a direct working interest can carry self-employment tax, and it is specifically excepted from the passive-activity rules, which cuts both ways.
How the payment is calculated
For every cost-free interest the arithmetic is the same: the owner's decimal interest, multiplied by the volume produced in the period, multiplied by the price received for it, less the deductions the instrument and the state permit, less severance and any ad valorem tax.
The decimal comes from the conveyance and the unit. For a lease royalty it is net mineral acres over unit acres, times the royalty fraction. For an override it is whatever fraction was carved, sometimes proportionately reduced to the assignor's interest — the phrase 'proportionately reduced' in an assignment can cut the expected payment substantially and is easy to miss.
Price received is not the front-month benchmark. It is the realised price at the point of sale, after quality, gravity and location differentials, which for natural gas in a constrained basin can be a long way from the headline.
The unit matters as much as the acreage. Pooling and unitisation combine tracts, and an owner's share of a horizontal well depends on how much of their tract falls inside the unit, not on how close the wellbore is to it.
How often it arrives
Monthly, after a division order is signed and the operator has established title. Payments can be suspended for title defects, for unlocatable owners, or below a minimum threshold, in which case they accumulate until the threshold is met or the year ends.
What erodes it
Every royalty shrinks. What differs is the mechanism and the speed.
This is the section that separates a royalty from a bond. Nobody promised you a number: the payment follows how much use there is, and use fades. A song is played less, a patent expires, a well produces less every year it runs. Where this misleads: reading last year's payment as a run rate. The honest question is not what it paid, but how many years of paying are left and at what level.
The decline curve
Production falls from an early peak along a curve engineers fit and publish as a type curve. Unconventional wells decline steeply in the first years and then flatten into a long tail. Every valuation of a royalty is an assumption about that curve.
Price and differentials
Realised prices depend on basin, quality and takeaway capacity. A widening basis differential cuts income without any change in production.
Lease termination (for overrides)
An overriding royalty ends with its lease. If production ceases and the lease lapses, a new lease over the same minerals creates a new royalty for the mineral owner — and nothing for the former override holder.
Post-production deductions
The single largest recurring dispute in the sector: what may be charged against a cost-free interest between the wellhead and the point of sale.
Operator behaviour
Drilling schedules, shut-ins, recompletions and the decision to develop at all belong to the operator. A royalty owner is a passenger.
Plugging and end of life
Marginal wells are eventually plugged and abandoned. For a royalty owner the income simply stops; for a working-interest owner the liability arrives at exactly that moment.
A mineral cheque is one long multiplication, and the boxes below run it. Your share of the drilling unit, multiplied by the fraction the lease gives the mineral owner, gives the decimal that appears on the operator's paperwork. That decimal, applied to the month's production and the price actually received, is the gross — and the deductions come off after that. One thing to watch: only the decimal is fixed. Production, price and the deductions all move, and the deductions are the most commonly disputed line on the statement.
Illustration: the decimal behind a mineral cheque
Your numbers, computed in your browser. This shows how a net revenue interest is built and what a month's gross would be at the volume and price you enter. It is arithmetic, not a quote, not a forecast and not an estimate of what any acreage pays — we do not carry commodity prices on this site and do not assert them.
Old leases were commonly 1/8 (12.5%); competitive leasing produced 3/16 (18.75%) and 1/4 (25%). A drafting convention, not a market rate.
The price actually received after differentials — not a benchmark quote.
Three figures come back. The net revenue interest is the decimal that appears on a division order: your share of the unit multiplied by the lease royalty fraction, carried to eight places because that is how operators calculate it. Gross is that decimal applied to the month's production and price, and the last figure is what remains once the deductions and severance tax you entered come out. The caveat: the decimal is the part that is fixed by documents, while production, price and deductions all move — and the deduction percentage is the line most often disputed.
Whether those deductions may be taken at all depends on the lease language and the governing state's rule, which is the most litigated question in the sector.
What diligence looks like
Diligence on a royalty is mostly document work: proving the right exists, proving the seller owns it, and proving the payments you were shown came from it. The easy mistake: a statement showing money arriving. A statement proves that a payment was made, not that the right behind it is unencumbered, correctly registered, or yours after the sale.
- Determine which interest is being offered — RI, ORRI, NPRI, NPI or WI — from the conveyance language, not the listing.
- For an override, read the underlying lease and confirm its status, term and continuous-development obligations.
- Check for 'proportionately reduced' language and compute the decimal yourself.
- Pull the wells' production history from the state regulator and fit the decline rather than annualising the last good month.
- Read the post-production cost provisions against the governing state's rule.
- Assess the operator: activity level, financial condition, and its record on royalty payment disputes.
- For any working interest, price plugging and abandonment liability, insurance, and the joint operating agreement's default and non-consent provisions before considering the revenue.
- For a package sold at auction, read the data room's title runsheet and the engineering assumptions — reserve categories, pricing deck and discount rate — rather than the headline reserve value.
Tax treatment
Cost-free royalty and override income is ordinary income on Schedule E, eligible for depletion, with severance taxes and permitted post-production costs deductible against it.
A working interest is different in kind: it is generally an active business interest, can attract self-employment tax when held directly, is excepted from the passive-activity loss rules, and carries the intangible drilling cost deduction that makes drilling partnerships attractive to some taxpayers and unsuitable for others.
Partnership vehicles issue Schedule K-1 rather than 1099, often late, and can create filing obligations in every state where the partnership has production. Trusts issue their own tax information booklet rather than a simple form.
The tax treatment of these interests is genuinely intricate and is one of the few places on this site where the general description above is not close to sufficient for a real transaction.
Listed vehicles with exposure to this
A research screen from our database, sorted by ticker, not ranked.
These trade on an exchange, so they solve the hardest problem with a royalty — that there is normally nobody to sell it to. What they add is a wrapper with its own costs, its own management and, in a trust's case, an end date. What would mislead: the yield shown is trailing, meaning it measures the last twelve months of payments against today's price. On a trust holding a pool that cannot be refilled, that figure describes a year that will not come round again.
These are the exchange-listed vehicles in our universe whose exposure overlaps this royalty type, in ticker order. The structure column is our own classification of the wrapper and decides how the rest of the row reads; the yield and dollar figures are trailing twelve-month distributions over the current price, not a forward estimate and not a promise about the next twelve months. The caveat: a listed wrapper around a royalty is a different instrument from the royalty itself — it prices daily, carries the wrapper's own costs and governance, and in a trust's case is winding down by design.
| Ticker | Name | StructureThe wrapper. A finite trust and an operating company behave very differently. | Price | Trailing 12m yieldThe cash paid over the last twelve months, over today's price. A year already gone, not a rate for the year ahead. | Trailing 12m paidWhat one share actually paid over those twelve months, in dollars. | Pays | Market cap | Yrs paying | Last ex-date |
|---|---|---|---|---|---|---|---|---|---|
| BSM | Black Stone Minerals, L.P. | Mineral and royalty partnership | $14.89 | 8.19% | $1.22 | Quarterly | $3.16B | 11.00 | Aug 06, 2026 |
| CRT | Cross Timbers Royalty Trust | Royalty trust | $10.61 | 5.29% | $0.56 | Monthly | $63.66M | 21.00 | Jul 31, 2026 |
| DMLP | Dorchester Minerals, L.P. | Mineral and royalty partnership | $28.93 | 11.04% | $3.19 | Quarterly | $1.40B | 23.00 | Aug 03, 2026 |
| KRP | Kimbell Royalty Partners, LP | Mineral and royalty partnership | $15.17 | 10.55% | $1.60 | Quarterly | $1.50B | 9.00 | Aug 17, 2026 |
| MARPS | Marine Petroleum Trust | Royalty trust | $4.90 | 6.43% | $0.32 | Quarterly | $9.80M | 41.00 | May 29, 2026 |
| MTR | Mesa Royalty Trust | Royalty trust | $2.65 | 5.65% | $0.15 | Monthly | $4.94M | 23.00 | May 29, 2026 |
| NRT | North European Oil Royalty Trust | Royalty trust | $8.56 | 11.80% | $1.01 | Quarterly | $78.67M | 39.00 | Aug 17, 2026 |
| PBT | Permian Basin Royalty Trust | Royalty trust | $34.61 | 1.09% | $0.38 | Monthly | $1.61B | 21.00 | Jul 31, 2026 |
| SBR | Sabine Royalty Trust | Royalty trust | $74.46 | 6.41% | $4.77 | Monthly | $1.09B | 21.00 | Aug 17, 2026 |
| SJT | San Juan Basin Royalty Trust | Royalty trust | $2.93 | — | — | Monthly | $136.56M | 24.00 | Apr 29, 2024 |
| TPL | Texas Pacific Land Corporation | Land and royalty company | $372.79 | 0.61% | $2.27 | Quarterly | $25.71B | 42.00 | Jun 01, 2026 |
| VNOM | Viper Energy, Inc. | Mineral and royalty company | $44.07 | 5.56% | $2.45 | — | $15.87B | 12.00 | Aug 13, 2026 |
| VOC | VOC Energy Trust | Royalty trust | $3.37 | 17.06% | $0.57 | Quarterly | $57.29M | 15.00 | Jul 30, 2026 |
Prices as of Aug 25, 2026.
A royalty trust is not a company. It is a fixed pool of interests in specific wells, dropped into a trust that is forbidden to buy anything new. The trustee collects what those wells produce, pays the trust's costs, and passes the rest through. Every distribution therefore contains a return of the buyer's own capital as the reserves run down, and the trust ends when the pool is exhausted or falls below a wind-up threshold written into the trust agreement. This is why a trailing yield on a trust overstates the future: the numerator is the last twelve months of a stream that is, by design, finite and declining. A company that owns minerals can buy more acreage and replace what depletes. A trust cannot.
Where interests like this change hands
EnergyNet
Minerals and energy
- What trades there
- Producing oil and gas properties, working interests, and mineral and royalty interests. It also runs online lease-sale auctions for government and institutional sellers.
- How the sale works
- Timed online auction with a reserve, plus sealed-bid and negotiated sales. Data rooms carry title runsheets, production history and, on larger packages, engineering.
- Typical buyer
- Operators adding acreage, mineral and royalty funds, family offices, and individual mineral owners consolidating around what they already hold.
US Mineral Exchange
Minerals and energy
- What trades there
- Mineral rights and royalty interests, listed on behalf of the owner.
- How the sale works
- Brokered marketing rather than an open outcry: the interest is packaged and shown to a network of buyers, offers are solicited, and the owner chooses. Closing runs through a deed and a division-order change with the operator.
- Typical buyer
- Mineral buyers and funds that hold to collect, rather than operators.
The Mineral Auction
Minerals and energy
- What trades there
- Mineral rights and royalty interests, mostly from individual and estate sellers.
- How the sale works
- Auction. The interest is catalogued with its production and title detail, marketed for a fixed window, then sold to the high bidder.
- Typical buyer
- Mineral funds and private buyers; sellers are frequently heirs settling an estate.
These are the visible venues. Most mineral and royalty interests never touch one. They move through a broker or a landman working a specific county, through an unsolicited offer letter mailed to an owner whose name appears in the county deed records, through an operator buying up the royalty under its own wells, and through probate when an estate is settled. County records are the real order book: ownership, leases, assignments and prior sale prices are filed at the courthouse where the land sits. Music is the same story one level up — the marketplaces are the retail end, and most catalogue value trades in privately negotiated deals brokered by specialist advisers. A price you see on a public venue is not a market quote for anything else.
Primary sources
The registers, regulators and collecting bodies that hold the authoritative record.
- US Energy Information Administration ↗ Production, reserves, prices and basin-level data
- Bureau of Land Management ↗ Federal leasing programme and lease sale results
- Texas Railroad Commission ↗ Well permits, completions and production records
- SEC EDGAR ↗ Reserve reports and trust filings for listed vehicles
Where to look
An auction marketplace where music and other intellectual-property royalty streams are sold, with historical payout statements published for each listing.
Listings disclose the payment history the sale price is being bid against
Visit Royalty Exchange ↗An online auction platform for oil and gas mineral rights, royalty interests and working interests, including some state and federal lease offerings.
A working interest carries operating costs and liability; a royalty interest does not
Visit EnergyNet ↗The US organisation designated to collect and distribute digital performance royalties for sound recordings to rights owners and performers.
Covers the recording, which is a separate right from the underlying composition
Visit SoundExchange ↗A performing rights organisation that licenses public performance of musical works and distributes the resulting royalties to songwriters and publishers.
Songwriters affiliate with one performing rights organisation at a time
Visit ASCAP ↗Listed for reference. A row without a Sponsored badge is a plain outbound link and we earn nothing from it.
Frequently asked
What is the difference between a royalty and an overriding royalty?
Why is a working interest not a royalty?
Can a royalty interest pay nothing while wells are producing?
What are post-production costs?
How should decline be handled when looking at an interest?
Research only. Nothing on this page is investment, tax or legal advice, and no part of it recommends buying or selling any royalty interest, security or property. Every figure shown in a table comes from our database; everything else describes how these instruments are structured. The documents governing a specific interest override every general statement here.