“Free of Cost Forever” Does Not Shift Royalty Valuation Downstream Absent Clear Valuation-Point or Gross-Proceeds Language (Tex. 2026)

I. Introduction

In Fasken Oil and Ranch, Ltd., Fasken Land and Minerals, Ltd., and Fasken Management, LLC, as General Partner of Fasken Oil and Ranch, Ltd., and Fasken Land and Minerals, Ltd. v. Baldomero A. Puig, III, Emily P. Kenna, James W. Puig, and Priscilla P. Oberton, the Supreme Court of Texas revisited a recurring royalty-accounting dispute: when a deed reserves a “free of cost” nonparticipating royalty, is the royalty calculated at the wellhead (with the royalty owner bearing postproduction costs) or on the downstream sales price of processed gas (with no postproduction-cost burden)?

The controversy arose from a 1960 deed (the “Puig Deed”) reserving an undivided 1/16 “Non-Participating Royalty” in oil and gas “that may be produced from the above described acreage,” to be paid or delivered to the grantor “free of cost forever.” Fasken, the operator/successor to the original grantee, historically valued the royalty “at the well” using a workback approach—starting with downstream sales proceeds and deducting postproduction costs (transportation, treating, processing) to reach wellhead value. In 2021, the royalty owners sued, arguing “free of cost forever” barred deduction of postproduction costs and required payment on the downstream sales price for processed products.

The trial court agreed with the royalty owners and certified an interlocutory appeal on a controlling question: whether “free of cost forever” precludes deduction of postproduction costs. The court of appeals affirmed, reading Chesapeake Exploration, L.L.C. v. Hyder to support a downstream, cost-free royalty. The Supreme Court of Texas reversed, holding the deed’s text fixes the royalty on minerals “produced” (i.e., at the well), and “free of cost forever” does not, by itself, reallocate postproduction costs or shift valuation downstream.

II. Summary of the Opinion

The Court held that, unless the parties clearly agree otherwise, a cost-free royalty is free of exploration and production costs but bears postproduction costs incurred to enhance and transport raw minerals for downstream sale. The Puig Deed reserves a royalty in minerals “produced from the above described acreage,” which—by plain meaning and by Texas royalty doctrine—signals a wellhead valuation of raw, unprocessed minerals. The phrase “free of cost forever” merely reiterates the default rule that royalty is free of production costs; it does not convert a royalty on produced minerals into a royalty on processed, downstream products.

Because the deed contains neither (1) language moving the valuation point downstream (e.g., “proceeds,” “gross proceeds,” “amount realized,” or similar point-of-sale measures) nor (2) language expressly adding postproduction costs back into the royalty base, the Court concluded postproduction costs may be deducted to work back from downstream sales to wellhead value. The Court reversed the court of appeals, rendered partial summary judgment for Fasken, and remanded.

III. Analysis

A. Precedents Cited (and How They Drove the Result)

1. Devon Energy Prod. Co. v. Sheppard

The Court anchored the governing framework in Devon Energy Prod. Co. v. Sheppard, which restated the modern Texas approach: royalties are generally free of production costs but not postproduction costs, and parties can deviate only through language that (a) changes the valuation point or (b) adds postproduction costs to the royalty base. The Court treated Devon as both a doctrinal summary and an interpretive discipline: the deed must “plainly and in a formal way” indicate an intent to “operate differently.” Applying Devon, the Court found the Puig Deed does neither—no downstream valuation point and no add-back mechanism—so the default allocation controls.

2. Heritage Res., Inc. v. NationsBank

Heritage Res., Inc. v. NationsBank supplied the critical “at the well” logic: when value is determined at the well, postproduction costs are not “deducted” from the royalty—they are part of the calculation that converts downstream proceeds into wellhead value. The Court emphasized the mathematical/structural point often missed in drafting disputes: a wellhead-valuation clause and a “no deductions” clause can coexist without eliminating postproduction charges, because the royalty base itself is already netted back to the well. The Court cited Heritage to reinforce that anti-deduction phrasing, standing alone, usually restates freedom from production costs unless paired with language moving valuation downstream or changing the base.

3. BlueStone Nat. Res. II, LLC v. Randle

BlueStone Nat. Res. II, LLC v. Randle provided two key tools: (i) clarification that “gross proceeds” (and similar formulations) generally indicate point-of-sale valuation without deduction of postproduction costs (absent limiting language), and (ii) confirmation that the “workback method” is a proxy for “market value at the wellhead” when comparable at-the-well sales are absent. The Puig Deed’s “produced from the above described acreage” language was contrasted with the “gross proceeds” family of terms; because the deed lacks proceeds-type language, Randle supported the Court’s conclusion that wellhead valuation remains the default.

4. Exxon Corp. v. Middleton

Exxon Corp. v. Middleton was cited for two propositions that shaped the Court’s framing: “Production” refers to actual extraction at the surface, and if parties intend royalties to be calculated on an amount-realized/proceeds standard, they “could and should” say so with proceeds-type drafting. That caution bolstered the Court’s refusal to infer a downstream valuation point from silence plus “free of cost forever.”

5. Burlington Res. Oil & Gas Co. v. Tex. Crude Energy, LLC

Burlington Res. Oil & Gas Co. v. Tex. Crude Energy, LLC influenced two central parts of the opinion. First, it supported the conceptual separation between raw, produced gas and enhanced, processed gas—downstream price reflects wellhead value only after subtracting reasonable postproduction costs. Second, it shaped the Court’s skepticism of interpretations under which royalty value would irrationally depend on whether payment is made in cash or delivered in kind. The Court used Burlington Resources to argue that a coherent deed construction should avoid making the contract’s economics turn on an unspecified party’s ability to elect a payment method.

6. Carl v. Hilcorp Energy Co.

Carl v. Hilcorp Energy Co. served as a close textual analogue. There, “gas … produced from said land” language (alongside “market value at the well”) confirmed that the royalty interest arises at the well in minerals “as they come out of the ground.” The Court treated “produced from the above described acreage” as functionally equivalent in what matters most: it identifies the point and quality of the royalty-bearing substance as produced, raw minerals—not downstream products.

7. French v. Occidental Permian Ltd.

The Court invoked French v. Occidental Permian Ltd. (quoted through Burlington Resources) for the proposition that processed-gas sales prices incorporate added value from postproduction operations. This reinforced the Court’s key economic premise: if you value at the downstream market, you must confront whether the royalty shares in enhanced value and who pays for creating it—an allocation that Texas law does not infer without clear drafting.

8. Danciger Oil & Refineries, Inc. v. Hamill Drilling Co.

Danciger Oil & Refineries, Inc. v. Hamill Drilling Co. supported the long-standing distinction between gas “if, as and when produced” and gas after processing into a higher-value product. The Court used it to show that Texas law has long treated “produced” language as pointing to the raw commodity at extraction, not a refined product category.

9. Temple-Inland Forest Products Corp. v. Henderson Family Partnership, Ltd.; Watkins v. Slaughter; Altman v. Blake; Wintermann v. McDonald

The Court referenced Temple-Inland Forest Products Corp. v. Henderson Family Partnership, Ltd. to explain why “free of cost” phrasing is often used to clarify that a reserved interest is a royalty (free of production costs) rather than a mineral interest (which typically bears development/operating costs). Watkins v. Slaughter and Altman v. Blake were cited to show that “in, to and under … and that may be produced” language often denotes a mineral interest unless other text (like “free of cost” and “Non-Participating Royalty”) indicates royalty intent. Wintermann v. McDonald was discussed only to distinguish statutory/state-grant contexts from private conveyances; the Court emphasized that strict construction favoring the State does not apply between private parties.

10. Wenske v. Ealy; Nettye Engler Energy, LP v. BlueStone Nat. Res. II, LLC; Barrow-Shaver Res. Co. v. Carrizo Oil & Gas, Inc.

These cases supplied general interpretive rules: Wenske v. Ealy furnished the “plainly and in a formal way” deviation standard. Nettye Engler Energy, LP v. BlueStone Nat. Res. II, LLC and Barrow-Shaver Res. Co. v. Carrizo Oil & Gas, Inc. were used for deed-construction principles: harmonize provisions, apply plain meaning, and do not rewrite instruments “under the guise of interpretation.”

11. Chesapeake Exploration, L.L.C. v. Hyder (Distinguished)

The court of appeals relied heavily on Chesapeake Exploration, L.L.C. v. Hyder, but the Supreme Court treated Hyder as context-specific rather than a broad “cost-free means no postproduction costs” rule. In Hyder, the decisive clue was not “cost-free” alone; it was the parenthetical “(except only its portion of production taxes).” Because production taxes are a postproduction expense, the Court in Hyder reasoned that exempting taxes from “cost-free” would be nonsensical if “cost-free” referred only to production costs. The Puig Deed lacks any comparable textual signal (no parenthetical carveout of a postproduction expense), so Hyder did not justify inferring downstream valuation or a postproduction-cost prohibition.

12. Myers-Woodward LLC v. Underground Servs. Markham, LLC

Myers-Woodward LLC v. Underground Servs. Markham, LLC was cited for the proposition that deed language contemplating “paid or delivered” can create an in-kind royalty conceptually deliverable at the well. That supported the Court’s point that the deed’s structure is consistent with a wellhead-based royalty that can be satisfied either by delivery of raw production or by its cash value—without implying downstream valuation.

13. Clifton v. Johnson (Course of Performance Not Controlling, but Confirming)

Although the Court stated its construction “turns solely on the deed’s text,” it noted that the parties’ historical payment practice aligned with its interpretation. Citing Clifton v. Johnson, the Court observed it would be “surprising” for parties to misunderstand their instrument from the outset—using that observation as a confirmatory (not dispositive) point after concluding the deed is unambiguous.

B. Legal Reasoning

  1. Start with the default Texas rule. A nonparticipating royalty “entitles its owner to a share of the production proceeds, free of the expenses of exploration and production,” but it “usually” bears postproduction costs (treatment/processing, compression, transportation, and certain taxes) necessary to prepare and move minerals for sale.
  2. Ask whether the instrument clearly “operates differently.” The Court reiterated that deviation requires clear drafting—typically by (a) shifting the valuation point downstream or (b) expressly expanding the royalty base to include postproduction costs.
  3. Read the Puig Deed’s valuation language as wellhead-focused. The deed reserves royalty in minerals “produced from the above described acreage.” The Court treated “produced” as extraction/creation of the product at the wellhead, not refinement or enhancement downstream. Thus, the deed identifies both (i) the place and (ii) the quality/state of the minerals as they emerge from the ground.
  4. Reject “free of cost forever” as a downstream-valuation trigger. “Free of cost forever” was read as confirming the traditional royalty attribute: no production costs. “Forever” was interpreted as temporal duration of the interest, not a geographic relocation of valuation. Critically, the phrase does not mention proceeds, gross proceeds, amount realized, sales price, or any downstream market, and it does not include add-back language.
  5. Use the “in kind” option as structural corroboration, not as a loophole. The deed allows the royalty to be “paid or delivered,” but does not specify who chooses. The Court found it implausible that the deed intended radically different economic outcomes (and strategic behavior) depending on an unspecified election right. A wellhead-based royalty harmonizes the cash-or-deliver alternative by keeping value consistent regardless of delivery method.
  6. Conclude that workback deductions are permissible. Because the royalty is on wellhead production, postproduction costs may be used to work back from downstream sales proceeds to determine market value of raw minerals at the well.

C. Impact

  • Clarifies the limited force of “free of cost” phrases in deeds. This opinion makes explicit that “free of cost forever,” without more, is not a magic phrase that converts an at-the-well royalty into a downstream proceeds royalty. It will likely curb litigation arguments that treat generalized cost-free wording as an implied “no postproduction costs” clause.
  • Strengthens the “valuation point first” approach. The Court’s analysis re-centers royalty disputes on where valuation occurs (wellhead vs. point of sale), emphasizing that cost-free language cannot be read in isolation.
  • Drafting consequences for conveyancers and title lawyers. Parties wanting downstream valuation must use proceeds-type language (e.g., “gross proceeds,” “amount realized,” “price actually received”) or unambiguous add-back provisions. Conversely, parties wanting wellhead valuation can expect “produced from” and similar production-based language to be read as wellhead-focused absent contrary text.
  • Limits overreading of Hyder. The Court’s careful contextualization of Chesapeake Exploration, L.L.C. v. Hyder reduces the risk that Hyder is applied as a blanket rule whenever “cost-free” appears.
  • Operational/accounting stability. Operators using workback methodology for older deed royalties gain stronger support when the instrument ties the royalty to “produced” minerals and lacks proceeds language or add-back provisions.

IV. Complex Concepts Simplified

Nonparticipating royalty interest (NPRI)
A right to receive a stated share of production (or its value) without the right to lease or participate in bonus/delay rentals, and typically without paying exploration and production costs.
Production costs vs. postproduction costs
Production costs are incurred to find and extract minerals (drilling, completing, lifting). Postproduction costs are incurred after extraction to make the product saleable and get it to market (gathering, compression, treating, processing, transportation).
Valuation point (“at the well” vs. downstream)
If royalties are valued “at the well,” the royalty base is the value of raw product at the wellhead. If the only sales occur downstream, the value “at the well” is commonly computed by taking the downstream sales price and subtracting reasonable postproduction costs (the “workback method”). If valued downstream (e.g., “gross proceeds”), royalties are calculated on the sales proceeds at the point of sale, generally without deduction of postproduction costs.
Why “no deductions” language can be ineffective with wellhead valuation
When valuation is “at the well,” postproduction costs are not treated as itemized “deductions” from the royalty; they are part of determining what the wellhead value is. So a clause saying “no deductions for transportation/processing” may not change anything unless the instrument also changes the valuation point or the royalty base.
In-kind royalty
Instead of cash, the royalty owner can receive the physical product (their share of gas/oil). If a deed says “paid or delivered” but does not say who chooses, courts are reluctant to read the deed as creating economically unstable outcomes depending on an unstated election right.

V. Conclusion

The Supreme Court of Texas established a clear interpretive rule for deed royalties: “free of cost forever” does not, standing alone, shift royalty valuation from wellhead production to downstream sales of processed products, nor does it preclude postproduction-cost workback deductions. To displace the default allocation of postproduction costs, parties must use language that clearly changes the valuation point (proceeds/gross proceeds/amount realized or equivalent) or expressly adds postproduction costs to the royalty base. By distinguishing Chesapeake Exploration, L.L.C. v. Hyder and reaffirming the primacy of valuation-point drafting, the Court’s opinion provides stronger predictability for royalty accounting, deed construction, and future disputes over “cost-free” language in Texas oil-and-gas instruments.