Market value versus proceeds refers to the two basic ways an oil and gas lease sets the value on which your royalty is calculated: a market-value lease pays royalty on the prevailing market price (often specified "at the well"), while a proceeds lease pays royalty on the amount the lessee actually receives from its sale — a distinction that, together with where value is measured, determines your royalty base and how post-production costs are treated.
Your royalty is a fraction of the value of production — but leases do not all define that value the same way. Broadly, there are two families. A market-value (or "market price") lease bases royalty on the prevailing market value of the oil or gas. A proceeds (or "amount realized") lease bases it on the actual proceeds the lessee receives when it sells the production.
When the lessee sells at the market price, the two give the same answer. They diverge when the lessee's actual sale price differs from the prevailing market — for example, under an old fixed-price contract — which is exactly where disputes have arisen.
Just as important as market-value-vs-proceeds is where the value is measured. Many leases specify value "at the well" — meaning the value at the wellhead, before the costs of gathering, processing, and transporting the gas to a downstream sales point. Because gas is usually worth less at the well than downstream, an "at the well" valuation effectively lets those post-production costs reduce the royalty base.
Leases that instead value production at the point of sale, or that expressly bar deductions, keep more of the downstream value in the royalty base. So the royalty valuation clause and the post-production-cost outcome are tightly linked — the valuation point often decides whether deductions apply.
The market-value question drove classic litigation: courts have held that a market-value-at-the-well royalty is based on prevailing market price, even if the lessee is locked into a lower-priced sales contract — so a lessee selling cheaply might still owe royalty on the higher market value. Separately, states split on whether "at the well" language permits post-production deductions, producing very different owner outcomes across jurisdictions.
The upshot is that two owners with the same production and royalty fraction can receive different royalty amounts purely because their leases value production differently.
When you read a lease or judge a royalty, look past the fraction to the valuation language: is royalty on market value or proceeds, and is it measured at the well or downstream, with or without deductions? That wording, more than the rate alone, determines what you are actually paid — and it is negotiable before you sign. This is distinct from the mechanics of the deductions themselves; see post-production costs.
Buckhead Energy reads the royalty valuation clause when evaluating leased minerals, since it drives the real royalty stream. This page is educational information, not legal advice — how these clauses apply depends on the lease and your state's law.
How to Read Your Royalty Check
Oil & Gas Encyclopedia — all terms
Educational information only — not legal, tax, or investment advice. Consult a qualified attorney, CPA, or landman about your specific situation.
A market-value lease bases royalty on the prevailing market price of the oil or gas; a proceeds lease bases it on the amount the lessee actually receives from its sale. They match when the lessee sells at market, and diverge when its actual sale price differs from the prevailing market.
That royalty value is measured at the wellhead, before gathering, processing, and transportation to a downstream sales point. Because gas is usually worth less at the well, "at the well" valuation effectively lets post-production costs reduce the royalty base.
Because their leases value production differently — market value vs. proceeds, and at the well vs. downstream, with or without deductions. That valuation language, more than the fraction alone, determines the royalty amount actually paid.
Under a market-value-at-the-well royalty, courts have held royalty is based on prevailing market price even if the lessee is locked into a lower-priced contract — so it can owe royalty on the higher market value. Outcomes depend on lease wording and jurisdiction.
Yes. Whether royalty is on market value or proceeds, where it is valued, and whether deductions are allowed are all lease terms you can try to negotiate before signing — and they affect your real royalty more than the headline rate alone.
Yes — Buckhead Energy is a direct buyer of mineral, royalty, NPRI, and ORRI interests across the United States, producing or non-producing. Buckhead Energy makes a free written offer, pays the title and closing costs, and charges no broker commission.
Buckhead Energy buys mineral and royalty interests across all 50 states and has completed acquisitions in 33 states. Buckhead Energy is a direct buyer, not a broker — we purchase mineral and royalty interests with our own capital. Buckhead Energy has been buying mineral and royalty interests since 2006. Buckhead Energy holds an A+ rating with the Better Business Bureau.
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