You Own the Land but Not the Minerals: How Lease Bonuses, Royalties, and Depletion Are Taxed

You bought 40 acres with a farmhouse, a barn, and a view. What the deed didn't spell out in plain English is that someone else — a long-dead farmer's heirs, a speculator from the 1950s, an energy company — owns everything underneath your topsoil. Or the reverse: you inherited a quarter-section of prairie you have never set foot on, and a landman is offering you $500 an acre just to sign a piece of paper.

Welcome to the split estate. In much of the United States, the surface and the minerals beneath it are separate property that can be owned, sold, and taxed independently. If you hold the mineral side — or lease it to someone who drills — the tax rules that apply to your checks are unlike anything else in your return. The bonus for signing is ordinary income the year you receive it, even if no well is ever drilled. The royalty checks are ordinary income too, but they come with a deduction so generous it can keep paying out after your investment basis has hit zero. And if the well sits in another state, you may owe that state a tax return you never expected.

Here is how each piece is taxed, where it goes on your return, and the records that keep you out of trouble.

The Split Estate: Two Properties Stacked on Top of Each Other​

A "split" or "severed" mineral estate means one party owns the surface and another owns the oil, gas, coal, gravel, or other minerals below it. Severance usually happened generations ago — a farmer sold the land but reserved "all oil, gas, and other minerals," and the reservation passed down through dozens of heirs. Each heir now owns an undivided fractional interest (a "mineral interest"), and any one of them can lease their share to a producer.

How do you know what you own? The answer is in the county land records, not in your memory of the closing. Look for mineral reservations or exceptions in your deed and the chain of title before it. A title search or a landman's ownership report will spell out your "net mineral acres" (your fractional share times the tract size) and any existing leases. If a producer wants to drill, you will eventually sign a division order — the document that confirms your decimal interest in production and directs the company where to send your checks. Keep every one; they are the source documents for everything below.

One distinction matters enormously for taxes: a royalty interest is a cost-free share of production — you bear none of the drilling or operating costs. A working interest means you share the costs (and get the drilling-cost deductions that come with them). Most landowners hold royalty interests, and this guide is written for them.

The Three Payments You'll Receive, and How Each Is Taxed​

Nearly every oil, gas, or mineral lease produces some combination of three payment types. All three are ordinary income — none is capital gain — but they differ in what deductions you can take against them.

Lease bonus: taxable now, drilled or not​

The bonus is the check that arrives when you sign — often quoted per net mineral acre. It is ordinary income in the year you receive it, even if the lease's primary term expires years later without a single well being drilled. The producer reports it in Box 1 of Form 1099-MISC, and you report it on Schedule E as rents received.

Two quirks deserve attention. First, you may claim cost depletion against the bonus (more on the mechanics below), which shelters part of it — but Congress specifically barred percentage depletion on bonuses and other amounts payable without regard to production (Section 613A(d)(5)). Second, the cost depletion on a bonus is contingent on extraction: if the lease terminates with no production, the bonus is effectively recharacterized as rent, and depletion you already claimed against it generally must be restored to income. The income itself, of course, stays taxable.

Delay rentals: ordinary income, no depletion at all​

Some leases let the producer pay an annual "delay rental" to keep the lease alive during the primary term without drilling. Like the bonus, it is ordinary income reported in Box 1 and on Schedule E. Unlike the bonus, no depletion of any kind is allowed against it — the payment buys time, not minerals.

Royalties: ordinary income with the best deduction in the Code​

Once a well produces, you receive periodic royalty checks — typically one-eighth to one-quarter of production value, depending on the lease, net of your share of production taxes. Royalties are ordinary income reported in Box 2 of Form 1099-MISC (which has just a $10 reporting threshold, so expect a form even for small amounts) and on Part I of Schedule E. Royalty income on Schedule E is not subject to self-employment tax, a meaningful savings versus the same dollars earned as business income.

What makes royalties special is depletion — the mineral owner's counterpart to depreciation.

Depletion: Depreciation's More Generous Cousin​

Buildings wear out; mineral deposits get used up. Depletion is the Code's allowance for that exhaustion, and you compute it two ways every year for each property and take the larger number.

Cost depletion: getting your basis back, unit by unit​

Cost depletion spreads your basis in the minerals over the recoverable units. The formula is simple:

Cost depletion = (adjusted basis ÷ total recoverable units) × units sold this year

If your inherited mineral interest has a $60,000 basis, engineers estimate 30,000 barrels are recoverable, and 3,000 barrels were produced this year, your cost depletion is $6,000. Each year's deduction reduces your basis, and when basis hits zero, cost depletion stops. Your check stubs and the operator's annual production statements supply the unit counts; your basis comes from what you paid (plus closing costs) or, for inherited interests, the fair market value at the date of death.

Percentage depletion: 15% of gross income, even after basis is gone​

Percentage depletion ignores your basis entirely. For oil and gas, qualifying royalty owners and independent producers deduct a flat 15% of gross income from the property under Section 613A. Because the deduction is not tied to what you invested, it can — legally and routinely — exceed your total basis and continue for the life of the well. That asymmetry is the single most valuable tax feature of owning minerals.

Three guardrails apply:

• The small-producer limit. Percentage depletion for oil and gas is capped at average daily production of 1,000 barrels of oil (or the gas equivalent, 6,000 cubic feet per barrel). Royalty owners with modest interests rarely bump into it, but it is computed across all your properties combined.
• The 65%-of-income limit. Total oil-and-gas percentage depletion cannot exceed 65% of your taxable income (computed without the depletion deduction). Disallowed amounts are not lost — they carry forward to the next year.
• The property-income limit. Depletion cannot exceed 100% of the taxable income from that property.

There is also a bonus for marginal production: oil and gas from stripper wells and other marginal properties can qualify for a rate above 15% (up to 25%) when crude prices are low. For 2026 the IRS set that rate at 15%, because the 2025 reference price of $63.40 a barrel was well above the trigger — so marginal and prolific wells share the same rate this year.

Solid minerals play by a nearby set of rules​

Coal, metals, stone, gravel, and other hard minerals use the Section 613 rate table instead of Section 613A: rates run from 5% (sand, gravel, peat) to 22% depending on the mineral, with coal and lignite at 10%. The income limit is tighter — 50% of taxable income from the property rather than 100% — and cost depletion works the same unit-by-unit way. If your royalties come from a limestone quarry or a coal seam rather than a wellhead, confirm your mineral's rate before you file.

Where It All Goes on Your Tax Return​

For a typical individual royalty owner, the compliance picture is refreshingly contained:

• Schedule E, Part I. Bonuses and delay rentals go on the "rents" line; royalties go on the "royalties" line. If you own interests in multiple properties, track income and depletion separately for each — the property-level limits demand it.
• Form 1099-MISC. Match every Box 1 and Box 2 amount against your check stubs before you file. Operators do misreport decimal interests, misspell names, and apply the wrong state withholding.
• Deductions on Schedule E. Deduct state severance (production) taxes and ad valorem (property) taxes on the mineral interest — these are usually withheld straight from your checks, so add them back as expenses rather than reporting only the net deposit. Legal fees to negotiate the lease, landman and title costs, and professional fees for depletion calculations are deductible too.
• No Schedule C, no self-employment tax. Royalty and bonus income from mineral interests you merely own is investment-style income on Schedule E, not a trade or business — even if the checks are large. (Owning a working interest is a different story; that pulls you toward trade-or-business treatment.)

The State Tax Trap: You Owe Where the Well Sits​

Here is the surprise that ambushes inheritors: royalty income is sourced to the state where the minerals lie, not where you live. If you live in Florida but inherited minerals under a New Mexico section, New Mexico wants its cut — and it collects in advance. New Mexico requires producers to withhold its Oil and Gas Proceeds tax from payments to nonresidents. Pennsylvania requires lessees to withhold a flat 3.07% from nonresident lessors. Colorado withholds severance tax at the wellhead and issues annual withholding statements, and West Virginia enacted its own nonresident royalty withholding regime.

Practically, that means:

1. Expect state withholding on your checks if you live outside the producing state, and keep the annual withholding statements (they have state-specific form numbers, not federal ones).
2. File a nonresident return in the producing state to reconcile the withholding — you may get some back, or owe more.
3. Claim a credit on your home-state return for taxes paid to the producing state, so the same dollar isn't taxed twice. (No-income-tax states offer no such credit, so the producing state's bite is final.)

Severance taxes deserve a second mention: they are a real cost of production that varies wildly by state and commodity, and every dollar withheld is deductible on your federal Schedule E. Reconciling gross royalties to net deposits without accounting for severance tax is the most common bookkeeping error in mineral accounting.

The 3.8% Surtax High Earners Forget​

Royalties are investment income, which means they generally count toward the 3.8% Net Investment Income Tax on top of ordinary income tax once your modified adjusted gross income crosses $200,000 (single) or $250,000 (married filing jointly). A landowner with a $90,000 salary and $160,000 in royalties is suddenly an NIIT taxpayer on a slice of that royalty income. Percentage depletion reduces the royalty income subject to both taxes, which makes claiming it correctly do double duty — but estimated-tax planning should assume the surtax applies until your preparer says otherwise.

Selling Your Mineral Rights: Mostly Capital Gain, With a Recapture String​

Hold minerals for more than a year and sell, and the gain is generally long-term capital gain — a much better rate than the ordinary-income treatment of the royalties themselves. That mismatch is exactly why buyers pay premiums for producing interests: they are buying an ordinary-income stream, while you are selling a capital asset.

Three adjustments complicate the math:

• Reduce your basis by the cost depletion you claimed over the years (and by percentage depletion to the extent it reduced basis before basis hit zero). Sloppy basis tracking here overstates your gain and your tax.
• Expect some ordinary-income recapture. Under Section 1254, part of your gain — generally up to the depletion deductions that reduced your basis, plus any drilling and development costs you deducted — is recharacterized as ordinary income. Royalty owners who never paid drilling costs usually face only modest recapture, and percentage depletion taken after basis reached zero is never recaptured.
• Inherited minerals start fresh. Heirs generally take a stepped-up basis equal to fair market value at death, which means little built-in gain and a brand-new cost-depletion base. If you inherited minerals years ago and never established that value, a retroactive appraisal may be the highest-ROI paperwork you ever buy.

Selling also ends your depletion, your state filing obligation for that property, and your division-order paperwork — a clean break that partial sellers (who carve off half their interest) don't get, since they must allocate basis between the piece sold and the piece kept.

Keep Records Like a Business, Even Though It Isn't One​

Mineral income rewards the organized and punishes the forgetful. Maintain a file — physical or digital — for each property containing the deed and title history, the signed lease, every division order, all 1099s, annual production statements, state withholding statements, severance-tax records, and a running depletion worksheet showing basis, units, and which method you claimed each year. When interests pass to heirs, that file is worth real money: it establishes the basis step-up and prevents the next generation from paying tax twice on the same dollars.

This is also where your bookkeeping system earns its keep. Royalty income arrives net of taxes and fees across multiple properties, states, and operators; tracking gross-versus-net per property, per year, is exactly the kind of structured, auditable record-keeping that plain-text accounting handles well — every check, every withholding line, and every depletion calculation visible in one version-controlled ledger instead of scattered across a shoebox of stubs.

Common Mistakes That Cost Mineral Owners Real Money​

• Treating the lease bonus as capital gain. It is ordinary income, full stop — one of the most frequently botched items on landowner returns.
• Skipping depletion entirely. Many small royalty owners leave the 15% deduction unclaimed, often because no one told them Schedule E has a line for it. Compute both methods every year.
• Reporting net checks without deducting severance tax. If $1,200 was withheld from a $10,000 royalty check, your income is $10,000 and your deduction is $1,200 — reporting $8,400 of income with no deduction usually overstates the bottom line once state credits are considered, and it never matches the 1099.
• Ignoring the producing state's return. Nonresident withholding is not your final tax; it is a down payment. File the return.
• Confusing a working interest with a royalty interest. Signing a joint operating agreement or paying a share of drilling costs changes your tax posture completely — different deductions, different forms, potentially self-employment tax. Know which one you hold before you sign.
• Letting inherited basis go undocumented. Without a date-of-death valuation, you cannot claim cost depletion and you cannot compute gain correctly on a sale.

Keep Your Royalty Income Organized From the First Check​

Mineral income looks like mailbox money until tax season reveals it as a multi-property, multi-state accounting project — gross versus net royalties, per-property depletion worksheets, state withholding statements, and a basis ledger that may outlive you. Maintaining clear financial records from the first bonus check is what turns that complexity into routine. Beancount.io provides plain-text accounting that gives you complete transparency and control over your financial data — no black boxes, no vendor lock-in. Get started for free and see why developers and finance professionals are switching to plain-text accounting.