Disputes between mineral producers and royalty holders often center on how to value extracted minerals. Because oil and gas typically increase in value after post-production processes, such as treatment, compression, and transportation, the point at which a royalty is valued can significantly affect payments. Royalty owners generally prefer valuation at the downstream point of sale, while producers favor valuation at the wellhead, where costs have not yet been incurred.
On April 10, 2026, the Texas Supreme Court delivered its opinion in Fasken Oil and Ranch, Ltd. v. Puig, a case addressing whether the deed’s language allowed the operator to deduct a share of post-production costs from a nonparticipating royalty interest (NPRI). The case fits within a line of recent decisions clarifying when royalty language creates a “cost-free” interest. See, for example, Chesapeake Exploration, L.L.C. v. Hyder; BlueStone Natural Resources II, LLC v. Randle; Carl v. Hilcorp Energy Company; and Devon Energy Production Co., L.P. v. Sheppard.
The dispute turned on the interpretation of the “Puig Deed,” which reads as follows:
“There is SAVED, EXCEPTED AND RESERVED, in favor of the undersigned, B.A. Puig, Jr., out of the above described property, an undivided one sixteenth (1/16) of all the oil, gas and other minerals, except coal, in, to and under or that may be produced from the above described acreage [emphasis added], to be paid or delivered to Grantor, B.A. Puig, Jr., as his own property free of cost forever [emphasis added]. Said interest hereby reserved is Non-Participating Royalty ….”
Fasken argued this language established a valuation based on minerals “produced from the above described acreage,” that is, the value of the minerals at the wellhead. The Puigs argued that the royalty was calculated based on a downstream sales price that was implied by the “free of cost forever” language and the absence of any specific valuation point for the produced minerals.
The Court’s Framework
The Court began with a settled rule: absent contrary language, an NPRI is subject to post-production costs. An NPRI may typically free itself from post-production costs either (1) by setting the valuation point of the royalty downstream of the well, or (2) by employing explicit terms that add some or all post-production costs to the royalty base.
The Court concluded that the Puig Deed did neither.
“Produced from the Acreage” Sets A Wellhead Valuation Point
A central issue was whether the phrase “produced from the above described acreage” established a downstream valuation point. The Court held it did not.
Relying on prior decisions, the Court explained that “production” refers to bringing minerals to the surface. Thus, a royalty tied to minerals “produced” generally reflects their value at the wellhead. The Court emphasized that this language identifies the physical point at which the royalty interest arises, when the minerals are extracted, not after they are enhanced through downstream processes.
Although the deed did not include the explicit phrase “market value at the well,” the Court found the language functionally equivalent in context. By tying the royalty to production from the land, the deed indicated that valuation occurs at the wellhead. Accordingly, the royalty owners could only prevail if other language in the deed clearly shifted post-production costs.
“Free of Cost Forever” Does Not Eliminate Post-Production Costs
The Puigs relied heavily on the phrase “free of cost forever.” The Court rejected this argument, holding that the phrase does not alter the valuation point or eliminate post-production costs.
First, the Court interpreted “forever” as referring to the duration of the royalty interest, not the location of valuation. Second, the Court emphasized that, when paired with a wellhead valuation point, general “cost-free” language typically refers only to production costs, not post-production costs. In other words, it confirms that the royalty owner does not bear the expense of exploring for and producing the minerals, but it does not address costs incurred after production.
The Court further noted that the deed lacked the kind of language such as “amount realized,” “proceeds,” or “gross value received,” that would tie valuation to downstream sales and potentially eliminate post-production deductions. Without such terms, the general rule applies.
Contrast with Hyder: Why the Outcome Differs
The Court’s reasoning becomes clearer when contrasted with Chesapeake Exploration, L.L.C. v. Hyder.
In Hyder, the Court held that an overriding royalty described as “cost-free (except only its portion of production taxes)…” was not subject to post-production costs. The inclusion of a specific exception for production taxes indicated that all other costs were excluded. That context gave meaning to the “cost-free” language.
No such qualifier appeared in the Puig Deed. The phrase “free of cost forever,” standing alone, did not identify which costs were excluded or demonstrate a clear intent to shift post-production costs.
The cases also differ in how the royalty was measured. In Hyder, the royalty was based on “gross production,” which the Court interpreted as describing the volume used to calculate the royalty, not the valuation point. That left room for the “cost-free” language to operate on the royalty calculation without being constrained by a fixed valuation point.
In Fasken, however, the royalty was tied to minerals “produced from the above described acreage,” which the Court interpreted as fixing the valuation point at the wellhead. Once that valuation point was established, general “cost-free” language could not alter the allocation of post-production costs.
Taken together, the decision reflects a narrower view of “cost-free” language than Hyder might suggest. Absent clear textual signals, general phrasing will not overcome a wellhead valuation framework.
In-Kind vs. Cash Delivery
The Court also considered the deed’s provision allowing payment “in kind” or in cash. It reasoned that if the royalty were cost-free when paid in cash but not when delivered in kind, the producer would have an incentive to choose the method that minimized its financial burden. The deed, however, did not specify who controlled that choice.
The Court found it more plausible that the parties intended a consistent valuation method regardless of delivery form. A wellhead valuation achieves that consistency, as it produces equivalent value whether royalty is paid in kind or in cash.
Course of Conduct as Supporting Evidence
Finally, the Court noted that the parties’ historical conduct supported its interpretation. The Puigs had long accepted royalty payments reduced by post-production costs. While not dispositive, this course of performance was consistent with the Court’s reading of the deed and reinforced its conclusion.
Importantly, the Court treated this evidence as confirmatory rather than determinative, maintaining that the deed’s text remained the primary basis for interpretation.
Conclusion
Fasken reinforces the Texas Supreme Court’s approach to royalty interpretation: the outcome depends on the specific language of the instrument read as a whole. The decision confirms that (1) language tying royalties to minerals “produced” generally sets a wellhead valuation point; (2) “cost-free” language, without more, does not eliminate post-production costs; and (3) parties seeking to create a truly cost-free royalty must do so through clear and explicit drafting.
Rather than announcing a new rule, the Court applied established principles to a familiar dispute, underscoring the importance of precision in royalty provisions. For practitioners and drafters, the lesson is straightforward: avoiding post-production costs requires more than general language; it demands unmistakable clarity regarding both valuation and cost allocation.
Kuiper Law Firm, PLLC specializes in oil and gas issues; if you have any questions about the information in this article, or how it applies to you and your operations, do not hesitate to contact us.