# Market Value vs. Proceeds Royalty

**Source:** Buckhead Energy Oil & Gas Encyclopedia (https://www.buckheadenergy.com/learn) — canonical: https://www.buckheadenergy.com/market-value-vs-proceeds

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.

## Two ways to set the royalty base
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.

## Where value is measured: "at the well"
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.

## Why this has produced landmark disputes
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.

## What it means for owners
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.

## Frequently asked questions

**What is the difference between a market-value and a proceeds royalty?**
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.

**What does "at the well" mean in a royalty clause?**
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.

**Why do two owners with the same royalty rate get paid differently?**
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.

**Can a lessee owe royalty on more than it was 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.

**Is the royalty valuation clause negotiable?**
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.

## Related terms
- [Post-Production Costs](https://www.buckheadenergy.com/post-production-costs)
- [Oil and Gas Royalties](https://www.buckheadenergy.com/oil-and-gas-royalties)
- [How to Read Your Royalty Check](https://www.buckheadenergy.com/how-to-read-your-royalty-check)
- [Basis Differential](https://www.buckheadenergy.com/basis-differential)
- [Oil & Gas Encyclopedia — all terms](https://www.buckheadenergy.com/learn)

_Educational information only, not legal or tax advice. Buckhead Energy is a direct buyer of oil & gas mineral and royalty interests._