Background and Parties

In 1960, B.A. Puig, Jr. conveyed Webb County ranchland to Palafox Exploration Company while reserving "an undivided one-sixteenth (1/16) of all the oil, gas and other minerals" to be "produced from the above described acreage, to be paid or delivered to Grantor, B. A. Puig, Jr., as his own property free of cost forever." Fasken Oil and Ranch, Ltd., as successor to Palafox, operates oil and gas wells on the property and historically calculated the Puigs' non-participating royalty interest (NPRI) by deducting postproduction costs—including transportation, treatment, and processing expenses—from the downstream sales price to arrive at the wellhead value of raw minerals.

The Royalty Calculation Dispute

In 2021, the Puigs challenged Fasken's decades-long calculation methodology, arguing that the "free of cost forever" language entitled them to royalties based on the full sales price obtained for processed gas at downstream markets, without any deduction for postproduction costs. The trial court granted summary judgment for the Puigs, and the San Antonio Court of Appeals affirmed, relying on Chesapeake Exploration, L.L.C. v. Hyder. The trial court certified an interlocutory appeal on the controlling question: "Does the [deed's] 'free of cost forever' language preclude the deduction of post-production costs?"

The Supreme Court's Analysis

Justice Bland, writing for the Court, reversed and held that the deed's plain language identified the wellhead as the valuation point. The Court emphasized that the deed reserved a royalty on minerals "produced from the above described acreage," not minerals transported, processed, or sold downstream. Applying established principles of deed construction, the Court stated:

The deed lacks language indicating that the royalty is calculated based on processed gas at a point downstream rather than gas produced at the well. Nor does the deed specify that the royalty is based on gross proceeds from a downstream sale.

The Court clarified that the "free of cost forever" language merely restates the default rule that royalties are calculated without deduction of exploration and production costs—costs incurred to bring minerals to the surface. The Court explained:

Unless the parties agree otherwise, a nonparticipating royalty is subject to postproduction costs incurred to prepare raw oil or gas for sale downstream, including taxes, treatment costs to render [the] minerals marketable, and transportation costs.

To deviate from this rule, the Court held, "royalty agreement must plainly and in formal way express parties' intent to operate differently." The Court found no such language in the Puig Deed, noting that "[s]tanding alone, the phrase does not transform a royalty on raw minerals into a royalty on processed minerals sold downstream as products."

Implications for Oil and Gas Practitioners

This decision provides critical guidance for interpreting cost-free royalty clauses in mineral deeds and reinforces the distinction between valuation point and cost allocation. The Court's holding makes clear that generic "free of cost" language, without more, does not shift postproduction costs to operators or establish a downstream valuation point. Practitioners representing operators can cite Fasken to defend netback calculations in NPRI disputes where deeds reference minerals "produced" without specifying a downstream sales point. Conversely, royalty owners seeking to avoid postproduction cost deductions must negotiate explicit language setting valuation at a downstream point or adding postproduction costs to the royalty base. The decision also underscores the importance of historical payment practices, as Fasken had consistently deducted postproduction costs since 1960 without challenge until 2021. For transactional lawyers, Fasken highlights the need for precision in drafting royalty reservations, particularly when clients intend to deviate from default rules governing cost allocation between wellhead and point of sale.