How do I calculate my oil and gas royalty payments?
Estimate only. Actual checks reflect your division-order decimal, realized (not benchmark) prices, gas/NGL volumes, lease-permitted post-production deductions, and production that declines over time. Not tax or investment advice.
Quick answer: Monthly royalty ≈ your decimal interest × barrels sold × oil price, minus severance tax and any lease-permitted deductions. Your decimal interest = (net acres ÷ unit acres) × royalty fraction. Use the calculator below to estimate your check.
Royalty Calculator
The Formula, Unpacked
Step 1 — your decimal interest. Take your net mineral acres, divide by the drilling unit's acres, and multiply by your lease's royalty fraction. A 1/8 royalty was the old standard; modern leases commonly run 3/16 to 1/4. Your exact decimal appears on your division order — verify it against your lease before signing, because that number governs every check you will ever receive.
Step 2 — gross royalty. Multiply your decimal by the unit's monthly sales volume and the realized price. Note "realized" — operators sell at wellhead or hub prices that usually run a few dollars under the WTI headline number.
Step 3 — what comes out. Severance tax is withheld at the wellhead (Oklahoma: 5% for a new well's first 36 months, then 7%, plus a small excise; Texas oil: 4.6%). Depending on your lease language, the operator may also deduct post-production costs — gathering, compression, treating, transportation. "Cost-free royalty" clauses prevent this; silence usually permits it.
Why Your Checks Shrink Over Time
Every well declines — steeply in its first years, then more gently for decades. A check that starts at $7,800 a month can be $2,900 two years later with no change in price, purely from natural decline. Anyone projecting flat royalty income for a decade is selling something. When evaluating minerals or royalties to buy, price them on the decline curve, not the first check.
The Tax Side of Royalty Checks
Royalty income lands on Schedule E and is generally exempt from self-employment tax. Its best feature is percentage depletion (IRC §613A): 15% of your gross royalty income is sheltered from tax every year — and it keeps working even after you have recovered your full cost. What royalties do not get: the big drilling deductions. Intangible drilling costs and bonus depreciation belong to working-interest owners who fund the wells.
Royalties vs. Working Interest: Which Side of the Check Do You Want?
A royalty is the passenger seat: cost-free income, no liability, no deductions, and no say. A working interest is the driver's seat: you fund your share of the drilling, take real risk — and receive the tax treatment Congress reserved for the people who put wells in the ground, including deductions of up to 100% of the investment in year one. High earners comparing the two should run both sets of numbers; the worked math and calculator for the working-interest side is here, and our side-by-side comparison is here.
Do not take our word for it — look the wells up yourself.
We publish the actual state regulator filings for 2.24 million wells across Texas, Oklahoma, Kansas, New Mexico, Colorado and New York — what each county produces, how deep the wells run, who operates them, and what they have made to date. Free, no signup, sources documented.
In Simple Terms
Your royalty check follows one formula: your decimal interest, times the oil the well sells, times the price. Your decimal interest = (your net acres ÷ the drilling unit's total acres) × your lease's royalty fraction (usually 1/8 to 1/4). So 20 net acres in a 640-acre unit with a 3/16 royalty = 0.00586 of every sales dollar. If the unit sells 3,000 barrels in a month at $75, your check is about $1,300 before severance taxes and any post-production deductions. Use the calculator on this page to run your own numbers.
Legal / Technical Details
Royalty decimal = (net mineral acres / unit acres) × lease royalty rate, as stated on your division order. Gross royalty = decimal × unit production × realized wellhead price. Deductions vary by lease language: severance tax (in Oklahoma, 5% for a new well's first 36 months, then 7%, plus a ~0.095% excise) is withheld at the wellhead, and post-production costs (gathering, compression, treating, transportation) are deductible from royalties only where the lease allows. Royalty income is reported on Schedule E, is generally exempt from self-employment tax, and qualifies for 15% percentage depletion under IRC §613A — sheltering 15% of gross royalty income annually, even after basis is exhausted. Note royalties are passive-type investment income for most holders and, unlike working interests, generate no drilling deductions.
Real-World Example
A landowner inherits 40 net mineral acres inside a 640-acre horizontal drilling unit leased at a 3/16 (18.75%) royalty. Decimal interest: 40 ÷ 640 × 0.1875 = 0.01172. The unit's wells produce 9,000 barrels in a month at a realized $74: gross royalty = 0.01172 × 9,000 × $74 ≈ $7,800. Oklahoma withholds 5% severance ($390) and the lease permits $260 of gathering deductions, so the check lands near $7,150. Two years later the same wells, in natural decline, produce 3,600 barrels — the check follows production down to roughly $2,860 at the same price. The formula never changes; the volumes do.
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Investment Disclaimer
Past performance is not indicative of future results. All investments involve risk, including the potential loss of principal. The projections, examples, and estimates presented are for illustrative purposes only and are not guarantees of future performance.
Oil and gas investments are speculative and involve significant risks including but not limited to: commodity price volatility, drilling and completion risk, regulatory changes, and geological uncertainty. Returns may vary substantially from projections based on actual well performance, oil prices, and operating costs.
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