Court Opinion

ID: 9322769
Source: CourtListenerOpinion
Date Created: 2022-12-05 00:11:36.388502+00
Date Added: 2024-06-11T17:14:43.412595
License: Public Domain

NUMBER 13-21-00310-CV

                           COURT OF APPEALS

                  THIRTEENTH DISTRICT OF TEXAS

                    CORPUS CHRISTI – EDINBURG

KENNETH HAHN,                                                           Appellant,

                                             v.

CONOCOPHILLIPS COMPANY,                                                   Appellee.

                  On appeal from the 267th District Court
                        of DeWitt County, Texas.

                        MEMORANDUM OPINION

 Before Chief Justice Contreras and Justices Longoria and Tijerina
         Memorandum Opinion by Chief Justice Contreras

      This appeal, the second in the underlying trial court cause, concerns the

calculation of appellee ConocoPhillips Company’s (Conoco) mineral royalty payments

to appellant Kenneth Hahn in this oil and gas dispute. The trial court granted summary

judgment in favor of Conoco. By two issues, Kenneth contends that the trial court erred
by: (1) concluding that his non-participating royalty interest (NPRI) was reducible by a

landowner’s royalty contained in an oil and gas lease; and (2) awarding Conoco

attorney’s fees under the Uniform Declaratory Judgments Act (UDJA). Because we

hold that Kenneth’s royalty interest was not reducible by the relevant landowner’s

royalty provision and that the trial court erred by awarding Conoco attorney’s fees, we

reverse and render in part and remand in part.

                     I.     OVERVIEW OF RELEVANT TERMINOLOGY

      To frame the background facts in this case, the context as to what rights are at

issue in this appeal, and our forthcoming discussion, we begin by briefly defining

certain oil and gas terminology and the rights associated with a mineral estate.

             An instrument conveying land in fee simple transfers both the
      surface estate and all minerals and mineral rights, unless the instrument
      contains a reservation or expresses a contrary intention. Schlittler v.
      Smith, 128 Tex. 628, 101 S.W.2d 543, 544 (1937). The mineral estate is
      comprised of five severable rights: “1) the right to develop, 2) the right to
      lease, 3) the right to receive bonus payments, 4) the right to receive
      delay rentals, and 5) the right to receive royalty payments.” French v.
      Chevron U.S.A. Inc., 896 S.W.2d 795, 797 (Tex. 1995). The holder of the
      leasing privilege is the executive-interest holder. KCM Fin. LLC v.
      Bradshaw, 457 S.W.3d 70, 75 (Tex. 2015). The executive enjoys the
      exclusive right to make and amend mineral leases and, correspondingly,
      to negotiate for the payment of bonuses, delay rentals, and royalties,
      subject to a duty of utmost good faith and fair dealing to non-executive
      interest holders. Id. at 74–75 ([first] citing Lee Jones, Jr., Non–
      Participating Royalty, 26 TEX. L. REV. [569, 575 (1948)], and [then citing]
      Plainsman Trading Co. v. Crews, 898 S.W.2d 786, 789–90 (Tex. 1995)).
      “In Texas, a typical oil and gas lease actually conveys the mineral estate
      (less those portions expressly reserved, such as royalty) as a
      determinable fee,” with the possibility of reverter as a future interest.
      Luckel [v. White], 819 S.W.2d [459,] 464 [(Tex. 1991)].

           “A royalty interest derives from the grantor’s mineral interest and
      is a nonpossessory interest in minerals that may be separately

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       alienated.” Id. at 463. “The same instrument may convey an undivided
       portion of the mineral estate and a separate royalty interest, and the
       royalty interest conveyed may be larger or smaller than the interest
       conveyed in the minerals in place.” Id. A party possessing a royalty
       interest that does not include the right to lease the mineral estate, receive
       delay rentals, or bonus payments is referred to as a[n NPRI] holder. KCM
       Fin., 457 S.W.3d at 75.

Hysaw v. Dawkins, 483 S.W.3d 1, 8–9 (Tex. 2016). An NPRI “is non-possessory in that

it does not entitle its owner to produce the minerals himself. It merely entitles its owner

to a share of the production proceeds, free of the expenses of exploration and

production.” Plainsman Trading Co., 898 S.W.2d at 789. In basic terms, an NPRI is an

expense-free royalty interest in minerals, if such minerals are ever produced.

               Royalty interests may be conveyed or reserved “as a fixed fraction
       of total production” (fractional royalty interest) or “as a fraction of the total
       royalty interest” (fraction of royalty interest). Luckel, 819 S.W.2d at 464.
       A fractional royalty interest conveys a fixed share of production and
       “remains constant regardless of the amount of royalty contained in a
       subsequently negotiated oil and gas lease.” Coghill v. Griffith, 358
       S.W.3d 834, 838 (Tex. App.—Tyler 2012, pet. denied). In comparison, a
       fraction of royalty interest (as a percentage of production) varies in
       accordance with the size of the landowner’s royalty in a mineral lease
       and “is calculated by multiplying the fraction in the royalty reservation by
       the royalty provided in the lease.” Id.; see Luckel, 819 S.W.2d at 464.

Hysaw, 483 S.W.3d at 9. A “fraction of royalty” interest is also called a “floating

royalty” interest. Id. at 4.

                       II.     BACKGROUND & PROCEDURAL HISTORY

A.     The 2002 Partition Deeds

       Kenneth and his three siblings, George N. Hahn, Doris Steubing, and Charles

Hahn, owned interests in a 74.15-acre tract of land (the Parent Property) in Dewitt

County. Kenneth and George owned undivided one-half interests in the Parent

                                              3
Property’s surface estate, and each of the four siblings owned undivided one-fourth

interests in the property’s mineral estate. On August 23, 2002, Kenneth and George

executed two partition deeds which provided for exclusive possession of the surface

rights to approximately 37.07 acres each; Kenneth would receive the northeast half of

the Parent Property’s surface estate (Tract A), and George the southwest half (Tract

B).

B.    Kenneth Sells Tract A

      In September 2002, Kenneth entered into an earnest money contract with

William Paul Gips and Lucille Fay Gips for the sale of his interest in Tract A. In

December 2002, Kenneth executed the general warranty deed for Tract A to the

Gipses, which contained the following reservation:

      SAVE AND EXCEPT and there is hereby reserved unto [Kenneth] herein,
      his heirs and assigns, an undivided one-half (1/2) non-participating
      interest in and to all of the royalty [Kenneth] now owns, (same being an
      undivided one-half (1/2) of [Kenneth’s] one-fourth (1/4) or an undivided
      one-eighth (1/8) royalty) in and to all of the oil royalty, gas royalty and
      royalty in other minerals in and under and that may be produced from the
      herein described property. [Kenneth] . . . shall not participate in the
      making of any oil, gas or mineral lease covering said property, nor shall
      they participate in any rental or shutin gas well royalty to be paid under
      any such lease. However, such reservation is subject to reversionary
      interest to surface owner [fifteen] years from [June 9, 2002] . . . .

The sale excepted three-fourths of the mineral interests under Tract A, which belonged

to Kenneth’s three siblings.

C.    The Gipses Enter Into an Oil and Gas Lease

      In July 2010, the Gipses entered into an oil and gas lease with Conoco (the

                                          4
Conoco/Gips Lease), 1 from which the Gipses reserved a one-fourth landowner’s

royalty in any minerals produced. Included in the lease was a pooling provision noting

that Conoco may, at its discretion, pool Tract A with other surrounding properties. In

the event of pooling, Conoco would pay the Gipses a pro rata share of the development

based on the total acreage of the pooled unit.

D.     The 2011 Lease Ratification and Stipulation of Interests

       In July 2011, Kenneth signed a document ratifying the Conoco/Gips Lease. The

ratification notes in relevant part:

       WHEREAS, Kenneth Hahn owns a[n] [NPRI] in the oil, gas[,] and other
       minerals under [Tract A,] the land conveyed by the Lease.

              WHEREAS, it is the desire of Kenneth Hahn to adopt, ratify[,] and
       confirm the Lease.

               NOW, THEREFORE, in consideration of the premises and other
       valuable consideration, the receipt of which is hereby acknowledged, I,
       Kenneth Hahn, do hereby ADOPT, RATIFY, and CONFIRM the Lease in
       all of its terms and provisions, and do hereby LEASE, GRANT,
       DEMISE[,] and LET unto [Conoco], its successors and assigns, subject
       to and in accordance with all the terms and provisions of the Lease as
       fully and completely as if I had originally been named as Lessor in the
       Lease and had executed, acknowledged[,] and delivered the same. And
       I do hereby agree and declare that the Lease in all of its terms and
       provisions are binding on me and is a valid and subsisting oil, gas[,] and
       mineral lease.

       On October 1, 2011, Conoco pooled Tract A into what it calls the Maurer Unit

B, consisting of a combined 307.41 acres. In November 2011, Conoco requested that

Kenneth and the Gipses “stipulate as to their ownership” in Tract A and presented the

       1  The Gipses entered into a lease with Burlington Resources Oil & Gas, a Conoco subsidiary.
We refer to Burlington and Conoco collectively as Conoco.
                                                5
parties with a stipulation agreement for their signatures. Pursuant to Conoco’s request,

Kenneth and the Gipses stipulated that “it was the intent of the parties in the deed from

[Kenneth] to [the Gipses] . . . that the interest reserved was a one-eighth (1/8) ‘of

royalty’ for a term of [fifteen] years from June 9, 2002.”

E.     Kenneth Enters Into an Oil and Gas Lease of Tract B

       In August 2010, Kenneth entered into an oil and gas lease with Conoco covering

his one-fourth mineral interest in Tract B. Conoco also pooled the Tract B lease into

Maurer Unit B. In May 2012, Conoco issued a division order to Kenneth pursuant to

Conoco’s lease of Tract B, which certified the ownership of mineral interests in oil and

gas production from Tract B payable by Conoco. At an unspecified later date, Kenneth

“was informally advised by Conoco[] that it would no longer be crediting him with his

1/4 mineral interest in Tract B.” Kenneth stated that Conoco questioned his mineral

interest in Tract B on account of his and George’s August 2002 partition deeds.

According to Conoco, Kenneth conveyed all of his surface and mineral rights in Tract

B to George, and George conveyed all of his surface and mineral rights in Tract A to

Kenneth. If that were true, then prior to his sale to the Gipses, Kenneth would have

owned the entire surface estate and one-half of the mineral estate in Tract A, and no

rights—surface or mineral—in Tract B.

F.     Kenneth Files Suit

       In March 2015, Kenneth filed suit against the Gipses and Conoco “to confirm

his title and ownership of a one-fourth (1/4) mineral interest in and to” Tract B and “a

one-eighth (1/8) royalty interest in and to” Tract A, asserting claims of, among other

                                            6
things, trespass to try title and breach of lease agreement. 2 The parties filed several

cross- and counter-motions for summary judgment, and the trial court held a hearing

on the motions in October 2015. In November 2015, the trial court concluded in

relevant part that:

        i.       The Kenneth Hahn Partition Deed conveyed all of the grantor’s
                 interest in the oil, gas[,] and other minerals in and under [Tract B].

        ii.      The George Hahn Partition Deed conveyed all of the grantor’s
                 interests in the oil, gas[,] and minerals in and under [Tract A].

        iii.     The Gips[es’] Deed [from Kenneth] conveyed all of [Kenneth]’s
                 interest in the oil, gas[,] and minerals in and under [Tract A], only
                 reserving to . . . Kenneth Hahn[] a fraction of royalty and not a
                 fixed fractional royalty and thus entitles Kenneth Hahn and his
                 heirs, successors[,] and assigns a fraction of royalty that floats in
                 accordance with the size of the landowner’s royalty contained in
                 any present or future oil and gas lease and is equal to one-eighth
                 (1/8th) of the landowner’s royalty contained under present or
                 future leases for a term of [fifteen] years beginning June 9, 2002[.]

Thus, the trial court’s order resulted in the following division of interests in the Parent

Property:

        Severed Surface & Mineral Estate Post-2015 Summary Judgment
      Owner                     Interests in the Parent Property
                            Tract A                         Tract B
      Doris                 25% mineral interest; 0% surface interest
      Charles               25% mineral interest; 0% surface interest
      George    0% surface or mineral            100% surface & 50% mineral
                interests                        interest
      Kenneth   0% surface interest & 1/8        0% surface or mineral interest
                floating royalty interest for
                fifteen years beginning June
                9, 2002

        2 Kenneth’s live pleading, his fifth amended petition, includes claims for: (1) trespass to try title;
(2) breach of lease; (3) tortious interference with lease; (4) statutory underpayment of royalties under
Chapter 91 of the Texas Natural Resources Code; (5) foreclosure of lease interest; (6) money had and
received; and (7) unjust enrichment.
                                                      7
     The             100% surface interest & 50% 0% surface or mineral interest
     Gipses          mineral interest less
                     Kenneth’s 1/8 floating royalty
                     interest for a fifteen-year
                     term beginning June 9, 2002

G.      Kenneth’s First Appeal to this Court

        In 2016, Kenneth appealed the trial court’s summary judgment to this Court.

See Hahn v. Gips, No. 13-16-00336-CV, 2018 WL 771908, at *1 (Tex. App.—Corpus

Christi–Edinburg Feb. 8, 2018, pet. denied) (mem. op. on reh’g). In his nine-issue brief,

Kenneth argued, among other things, that the trial court erred: (1) in interpreting

Kenneth’s and George’s partition deeds and the interests in Tracts A and B thereby

conveyed; (2) by “interpreting the ‘Reservations from Conveyance’ section of

[Kenneth’s 2002 deed of Tract A to the Gipses] as reserving a 1/8 floating royalty,

rather than a 1/8 fixed royalty”; and (3) by “giving effect to the [faulty] . . . ‘Stipulation

of Interest’” between Kenneth and the Gipses.

        In February 2018, after reviewing the record, we concluded, among other things,

that: (1) the trial court erred in ruling that through their partition deeds, “Kenneth and

George transferred anything more than the surface estate of Tract A and Tract B to

each” other; (2) Kenneth reserved in the Tract A deed to the Gipses a fixed one-eighth

royalty for a fifteen-year term; and (3) because Kenneth’s deed to the Gipses was

unambiguous, the trial court erred by considering the 2011 stipulation of interest. Id. at

*6–8. 3 Represented visually, we held the parties’ interests in the Parent Property were

        3 We acknowledge that our 2018 memorandum opinion on rehearing contains an error in the

conclusion section regarding the mineral royalty interests Kenneth reserved in his Tract A deed to the

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as follows:

             Severed Surface & Mineral Estate Post-2016 Appeal
     Owner                     Interests in the Parent Property
                           Tract A                          Tract B
     Doris                 25% mineral interest; 0% surface interest
     Charles               25% mineral interest; 0% surface interest
     George    0% surface interest; 1/4         100% surface interest & 1/4
               mineral interest                 mineral interest
     Kenneth   0% surface interest & 1/8        0% surface interest & 1/4
               fixed royalty for fifteen years  mineral interest
               beginning June 9, 2002
     The       100% surface interest & 1/4      0% surface or mineral interests
     Gipses    mineral interest less
               Kenneth’s 1/8 fixed royalty for
               a fifteen-year term beginning
               June 9, 2002

        We remanded the case to the trial court “for any further proceedings consistent

with [our] opinion.” Id. at *9. Conoco appealed our decision to the supreme court,

which, after full merits briefing, denied the petition.

H.      A Royalty Calculation Dispute Arises on Remand

        On remand, a dispute arose between Kenneth and Conoco as to the calculation

of Kenneth’s royalty interest in the pooled Maurer Unit B based on Kenneth’s one-

eighth fixed NPRI in Tract A. 4 The parties agree that Tract A’s tract participation rate

Gipses. While Kenneth’s interests in Tract A were correctly described in our analysis section, our
conclusion erroneously referred to them as applying to the entire Parent Property. See Hahn v. Gips,
No. 13-16-00336-CV, 2018 WL 771908, at *9 (Tex. App.—Corpus Christi–Edinburg Feb. 8, 2018, pet.
denied) (mem. op. on reh’g). The parties both recognize and agree, however, that the reservation
applied only to Tract A.

        4   All issues related to the calculation of Kenneth’s royalty payments from Tract B were resolved
in the trial court and are not before this Court. Additionally, in August 2021, the Gipses and Kenneth
each nonsuited their claims against one another pursuant to a settlement agreement. Thus, this appeal
only concerns Kenneth’s and Conoco’s claims against each other.
                                                    9
in Maurer Unit B is 0.12058814, representing 37.07 acres (Tract A) divided by 307.41

acres (Maurer Unit B). That is, about twelve percent of Maurer Unit B’s production was

deemed attributable to Tract A. According to Kenneth, his royalty interest was to be

calculated by multiplying his one-eighth interest in Tract A by Tract A’s 0.12058814

pooled decimal participation rate for a mineral royalty interest decimal of 0.01507352.

For example, then, if Maurer Unit B produced $1 million in proceeds, he was due a

royalty payment of $15,073.52.

       Conoco disagreed and moved for a declaratory judgment counterclaim in March

2020, claiming for the first time that Kenneth’s July 2011 ratification of the Conoco/Gips

Lease meant that he was bound to all the lease’s terms. Because the Gipses leased

Tract A to Conoco for a one-fourth landowner’s royalty, Conoco argued that Kenneth’s

royalty should be subject to and diminishable by the Gipses’ one-fourth landowner’s

royalty. Stated another way, Conoco argued that notwithstanding this Court’s 2018

conclusion that Kenneth reserved a fixed one-eighth NPRI in Tract A, Kenneth’s

ratification of the Conoco/Gips Lease transformed his fixed NPRI into a floating one.

Consequently, according to Conoco, instead of receiving royalties based on one-eighth

of Tract A’s 0.12058814 pooled participation rate, Kenneth was to receive one-eighth

of one-fourth of the royalties based on that rate—represented graphically by the parties

as follows:

                                           10
Presenting the same example based on that calculation, if Maurer Unit B produced $1

million in proceeds, Kenneth would be due a check for $3,768.38.

       Conoco argued in its subsequent motion for summary judgment that the plain

language of Kenneth’s 2011 ratification of the Conoco/Gips Lease was unambiguous

and that Kenneth could not partially ratify the lease—i.e., he could not accept the

pooling provision while sidestepping the lease’s one-fourth landowner’s royalty

provision.

       Kenneth generally denied Conoco’s counterclaim and asserted affirmative

defenses. Pointing to this Court’s disposition in his 2016 appeal, Kenneth argued in his

subsequent motion for summary judgment that Conoco’s calculation was erroneous

because, as an owner of a fixed one-eighth NPRI in Tract A, his interest was

definitionally not diminishable by the landowner’s royalty, and he was thus being paid

one-fourth of the royalties that he was due. Kenneth also argued that his 2011

ratification of the Conoco/Gips Lease “does not (and does not purport to) transform

Kenneth’s fixed royalty into a floating one,” and in any event, Conoco’s “untimely

attempt to assert ratification . . . is barred by estoppel, waiver, . . . laches,” and the law-

of-the-case doctrine.

       The trial court considered the cross-motions for summary judgment and, in its

June 15, 2020 order, held that: (1) Kenneth “ratified [the Conoco/Gips Lease] and is

therefore bound by all terms in that . . . Lease”; (2) ”based on that ratification, the

royalty decimal that should have been used to calculate Kenneth[’s] . . . royalty interest

in Tract A . . . was 0.00376838”; and (3) Conoco “shall recover its reasonable and

                                              11
necessary attorney’s fees for pursuing [its] declaratory judgment claim.”

       This appeal by Kenneth followed.

                                III.     STANDARD OF REVIEW

       Our review of a summary judgment is de novo. Eagle Oil & Gas Co. v. TRO-X,

L.P., 619 S.W.3d 699, 705 (Tex. 2021). To be entitled to a traditional summary

judgment, a movant must establish there is no genuine issue of material fact so that

the movant is entitled to judgment as a matter of law. TEX. R. CIV. P. 166a(c); Painter

v. Amerimex Drilling I, Ltd., 561 S.W.3d 125, 130 (Tex. 2018). When both parties move

for summary judgment on the same issues and the trial court grants one motion and

denies the other, we consider the summary judgment evidence presented by both

sides, determine all questions presented, and render the judgment the trial court

should have rendered. Tarr v. Timberwood Park Owners Ass’n, 556 S.W.3d 274, 278

(Tex. 2018).

                          IV.          LAW-OF-THE-CASE DOCTRINE

       Because it is potentially dispositive, we first address whether the law-of-the-

case doctrine fully resolves this appeal.

A.     Applicable law

       The law-of-the-case doctrine refers to the principle under which questions of law

decided on appeal to the court of last resort will govern the case throughout its

subsequent stages. Hudson v. Wakefield, 711 S.W.2d 628, 630 (Tex. 1986). “By

narrowing the issues in successive stages of the litigation, the law of the case doctrine

is intended to achieve uniformity of decision as well as judicial economy and efficiency.”

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Id. “[T]he doctrine does not necessarily apply when either the issues or the facts

presented at successive appeals are not substantially the same as those involved on

the first trial.” Id. Accordingly, “when in the second trial or proceeding, one or both of

the parties amend their pleadings, it may be that the issues or facts have sufficiently

changed so that the law of the case no longer applies.” Id.

       Application of the law-of-the-case doctrine lies within the discretion of the court,

depending on the particular circumstances of the case. Briscoe v. Goodmark Corp.,

102 S.W.3d 714, 716 (Tex. 2003). The law-of-the-case doctrine does not necessarily

prevent a court from reconsidering its earlier decision if an intervening supreme court

decision effects a change in the controlling law. See City of Dallas v. Jones, 331

S.W.3d 781, 784 (Tex. App.—Dallas 2010, pet. dism’d); McCrea v. Cubilla Condo.

Corp., N.V., 769 S.W.2d 261, 263 (Tex. App.—Houston [1st Dist.] 1988, writ denied).

B.     Analysis

       Kenneth argues that this Court’s conclusion in his 2016 appeal that he reserved

a fixed one-eighth NPRI in Tract A resolves the question in this appeal. Conoco argues

that the law-of-the-case doctrine does not apply in that manner because (1) the issue

in this appeal is different from the issue in Kenneth’s 2016 appeal and (2) intervening

supreme court case law calls for our reconsideration of our prior holding.

       As noted, Kenneth’s initial appeal concerned what rights, if any, he maintained

after (1) his and George’s 2002 partition deeds and (2) his 2002 deed of Tract A to the

Gipses. See Hahn, 2018 WL 771908, at *1. On remand, Kenneth amended his petition,

and Conoco raised Kenneth’s 2011 ratification of the Conoco/Gips Lease in arguing

                                            13
for a lower royalty decimal rate. The issue of ratification was never argued to this Court

in Kenneth’s 2016 appeal. Id.; see Hudson, 711 S.W.2d at 630.

       One of the issues that was presented in the 2016 appeal was whether, through

his 2002 deed to the Gipses, Kenneth reserved a fixed or floating NPRI in Tract A. See

Hahn, 2018 WL 771908, at *1. We held that Kenneth reserved a fixed one-eighth NPRI,

and the supreme court denied Conoco’s subsequent petition for review in which the

issue was fully briefed. Accordingly, all else being equal, the law-of-the-case doctrine

dictates that determination will continue to govern in this case. See Hudson, 711

S.W.2d at 630. But, as discussed below, the fact that Kenneth maintained a fixed NPRI

is highly relevant to, but not itself dispositive of, the issue of whether Kenneth’s 2011

ratification of the Conoco/Gips Lease affected his royalty interest under Tract A. Simply

stating that Kenneth has a fixed NPRI under the deeds does not answer whether

Kenneth later agreed to nonetheless receive royalties at a lower rate. Accordingly, we

agree with Conoco insofar as it argues that our conclusion in Kenneth’s 2016 appeal

does not resolve the issue in this appeal.

       However, we disagree with Conoco’s contention that intervening supreme court

case law requires us to reconsider our holding that Kenneth maintains a fixed, rather

than floating, one-eighth NPRI in Tract A. Conoco directs us to the supreme court’s

decision in Concho Resources, Inc. v. Ellison, 627 S.W.3d 226 (Tex. 2021), to argue

that this Court erred by failing to give effect to Kenneth’s 2011 stipulation of interest.

By adding the word “of” in the phrase “of royalty,” the stipulation’s language potentially

indicates that through his 2002 deed to the Gipses, Kenneth reserved a floating

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royalty. 5 We never addressed or analyzed that issue as, in Kenneth’s 2016 appeal, we

held that the trial court improperly considered the stipulation in concluding that

Kenneth’s interest was a floating one:

        We further conclude that in construing [Kenneth and] the Gips[es’ 2002]
        deed, the trial court improperly considered the 2011 Stipulation because
        it violated the four corners rule. As stated throughout this opinion, we
        construe an unambiguous deed by examining only what is stated within
        the four corners of the instrument. See Luckel v. White, 819 S.W.2d 459,
        461 (Tex. 1991). The trial court concluded that [Kenneth and] the
        Gips[es’ 2002] deed was unambiguous, and so do we.

                Thus, the trial court erred in considering the stipulation because it
        was outside of the four corners of [Kenneth and] the Gips[es’ 2002] deed
        and immaterial in construing the unambiguous deed. See id.; see also
        Sun Oil Co. (Del.) v. Madeley, 626 S.W.2d 726, 732 (Tex. 1981) (holding
        that only when a contract is first found to be ambiguous may the courts
        consider the parties’ interpretation and where the meaning of a contract
        is plain and unambiguous, a party’s construction is immaterial); Harris v.
        Rowe, 593 S.W.2d 303, 306 (Tex. 1979) (holding that “great, if not
        controlling, weight should be given by the court to the interpretation by
        the parties themselves when a contract has uncertain meaning only[”]).
        Our conclusion today does not hold that stipulations or party’s
        interpretation may never be utilized in construing a deed. However,
        because the deed in this case is unambiguous and without uncertain
        meaning, we need not look outside the four corners here. Accordingly,
        we sustain Kenneth’s sixth issue.

Hahn, 2018 WL 771908, at *8 n.5.

        In Concho Resources, Inc., the supreme court considered the effect of a

boundary agreement executed by owners of adjacent property. 627 S.W.3d at 226.

Between 1927 and 2008, the relevant tracts were conveyed multiple times, and the

        5  See Hysaw v. Dawkins, 483 S.W.3d 1, 9 (Tex. 2016) (noting difference between a “fractional”
and “fraction of” royalty); see also Christopher Kulander, Fixed vs. Floating Non-Participating Oil & Gas
Royalty in Texas: And the Battles Rage On . . ., 4 TEX. A&M L. REV. 41, 44–46 (2016) (collecting and
comparing examples of deeds reserving fixed and floating royalties and noting relevance of the word
“of”).
                                                  15
acreage and location of the tracts were described differently in various deeds and

leases. Id. at 229. An oil operator, Samson, desired to drill a well on one of the

properties but discovered the conflicting boundary descriptions. Id. at 230. Samson

prepared a boundary stipulation noting that “a question has arisen among the [p]arties

as to the physical location” of the boundary between the two properties. Id. The

stipulation described the boundary in a way contrary to the original deed. Id. Both

mineral estate owners signed the stipulation, and various lessees, including Jamie

Ellison, purported to ratify the agreement. Id. Samson then drilled wells. Id. at 230–31.

       Jamie Ellison died in 2011. Id. at 231. In 2013, his wife, Marsha, filed suit against

Samson, alleging that her lease covers more acreage than that to which the mineral

owners stipulated. Id. The trial court granted summary judgment against Ellison. Id. at

232–33. This Court reversed, holding, inter alia, that the boundary agreement was

“close in nature to a ‘correction deed’ in which a party seeks to retroactively ‘correct

the defects and imperfections’ of the original deed.” Ellison v. Three Rivers Acquisition

LLC, 609 S.W.3d 549, 561 (Tex. App.—Corpus Christi–Edinburg 2019), rev’d sub nom.

Concho Res., Inc., 627 S.W.3d at 226. But to correct the deed, “the underlying deed

must still possess some ‘ambiguity or error’ to correct.” Id. We concluded that because

“the 1927 Deed was unambiguous and that there was no uncertainty regarding the

boundary between the [relevant two tracts,] . . . the 2008 Boundary Stipulation

agreement was invalid and void.” Id. at 562.

       The supreme court reversed our decision, holding that the boundary stipulation

was enforceable between the parties, and that Ellison ratified the agreement. Concho

                                            16
Res., Inc., 627 S.W.3d at 234. The court concluded that when a question arises

concerning a boundary location, parties may resolve the dispute by going to court or

by signing a boundary agreement. Id. It matters not whether an original deed is

unambiguous; if there is doubt in the minds of the parties as to a boundary, they may

settle the matter by agreement, even if it is later determined that the issue was

erroneously settled. Id. at 234, 235 n.12.

       The instant case is distinguishable in at least two respects. First, unlike Concho

and the cases cited therein, this case does not concern a boundary dispute. See id.;

Gulf Oil Corp. v. Marathon Oil Co., 152 S.W.2d 711, 714 (Tex. 1941); Levy v. Maddux,

16 S.W. 877, 878 (Tex. 1891); Houston Oil Co. of Tex. v. Singleton, 44 S.W.2d 479,

481 (Tex. App.—Beaumont 1931). Concho has yet to be extended to property issues

outside the boundary dispute context, and we do not take the liberty to do so here.

Second, in Concho, multiple conveyances and leases with conflicting boundary

descriptions evidently led to ambiguity in the minds of the parties as to the correct

boundary separating the properties, demonstrated by, among other things, the

boundary stipulation’s statement that a “question has arisen” as to the proper

boundary. In this case, there is no evidence in the 2011 stipulation of interest or

elsewhere that a “question arose” between the parties as to the interest that Kenneth

reserved by his 2002 deed of Tract A to the Gipses.

       Accordingly, because the issue of the 2011 stipulation has been argued to and

rejected by the supreme court in this very case, and because the supreme court’s

holding in Concho does not bear on our conclusion in Kenneth’s 2016 appeal, we follow

                                             17
our prior conclusion that Kenneth maintained a fixed one-eighth NPRI in Tract A

through June 8, 2017. We proceed to analyze whether Kenneth’s ratification of the

Conoco/Gips Lease affected that interest.

                                  V.       RATIFICATION

       It is undisputed that Kenneth ratified the Conoco/Gips Lease in its entirety. The

principal question before this Court is whether Kenneth, by doing so, transformed his

fixed one-eighth NPRI in Tract A into a floating NPRI subject to the Gipses’ one-fourth

landowner’s royalty listed in the lease. Kenneth argues that: (1) a fixed mineral interest

is definitionally not diminishable by a landowner’s royalty; (2) he could not be bound to

the landowner’s royalty clause because the Conoco/Gips Lease was not entered into

on his behalf; (3) the Gipses did not and could not lease his NPRI on his behalf; and

(4) the effect of his ratification was to agree to the lease’s pooling provision alone.

Conoco argues that Kenneth cannot “accept the benefits of ratifying the lease to obtain

the benefit of pooling, without also accepting the burdens of ratification such as being

bound by the lease’s royalty clause.” Conoco states that Kenneth “cites no Texas

authority that has adopted [a] theory allowing for ratification for pooling purposes only.”

As discussed below, we disagree with Conoco’s contentions. We further note that

Conoco cites no authority, and we have found none, where a fixed NPRI was converted

into a floating one in any circumstance.

A.     Applicable Law

       1.     General Principles of Ratification

       “Ratification is the adoption or confirmation by a person with knowledge of all

                                            18
material facts of a prior act which did not then legally bind him and which he had the

right to repudiate.” BPX Operating Co. v. Strickhausen, 629 S.W.3d 189, 196 (Tex.

2021) (quoting Wise v. Pena, 552 S.W.2d 196, 199 (Tex. App.—Corpus Christi–

Edinburg 1977, writ dism’d)). Ratification “is but an agreement, express or implied, by

one to be bound by the act of another performed for him.” Id. (quoting Dillingham v.

Anthony, 11 S.W. 139, 142 (Tex. 1889)); see Enserch Corp. v. Rebich, 925 S.W.2d

75, 84 (Tex. App.—Tyler 1996, writ dism’d by agr.) (“[R]atification is reserved for the

adoption of acts done only on behalf of the alleged ratifier.”); Rhodes, Inc. v. Duncan,

623 S.W.2d 741, 744 (Tex. App.—Houston [1st Dist.] 1981, no writ) (“There can be no

ratification of an act which is not done in behalf of, and does not purport to bind, the

person against whom the doctrine of ratification is invoked.”). “A principal may not, in

equity, ratify those parts of the transaction which are beneficial and disavow those

which are detrimental. Ratification extends to the entire transaction.” Land Title Co. of

Dall. v. F. M. Stigler, Inc., 609 S.W.2d 754, 757 (Tex. 1980); see BPX Operating Co.,

629 S.W.3d at 196; Plains Cotton Co-op. Ass’n v. Wolf, 553 S.W.2d 800, 804 (Tex.

Civ. App.—Amarillo 1977, writ ref’d n.r.e.) (“In equity, the conduct of one’s agent must

be either repudiated or ratified in toto.”). “Ratification is often treated as a mixed

question of law and fact. When the facts are uncontroverted, however, the court may

decide the question of ratification as a matter of law.” BPX Operating Co., 629 S.W.3d

at 196 (internal citations omitted).

       2.     Ratification in the Oil and Gas Pooling Context

       As noted, a mineral estate consists of five severable rights, namely the rights

                                           19
to: (1) develop; (2) lease; (3) receive bonus payments; (4) receive delay rentals; and

(5) receive royalty payments. Hysaw, 483 S.W.3d at 9 (citing French, 896 S.W.2d at

797). “A conveyance of a mineral estate need not dispose of all interests; individual

interests can be held back, or reserved, in the grantor.” French, 896 S.W.2d at 797.

“Thus, each attribute is a separate, distinct property interest that may be conveyed or

reserved in connection with a conveyance of a mineral interest.” Hamilton v. Morris

Res., Ltd., 225 S.W.3d 336, 344 (Tex. App.—San Antonio 2007, pet. denied).

       The holder of the leasing right is known as the executive interest holder. KCM

Fin. LLC, 457 S.W.3d at 75. “The executive enjoys the exclusive right to make and

amend mineral leases and, correspondingly, to negotiate for the payment of bonuses,

delay rentals, and royalties, subject to a duty of utmost good faith and fair dealing to

non-executive interest holders.” Hysaw, 483 S.W.3d at 9. In other words, “the executive

has the power to make and amend leases affecting the enjoyment of the non-

executive’s interests.” KCM Fin. LLC, 457 S.W.3d at 75. A caveat exists in the context

of pooling.

       In certain instances, a tract of land chosen for oil exploration or development

may be “of insufficient size to satisfy the state’s spacing or density requirements.”

Browning Oil Co., Inc. v. Luecke, 38 S.W.3d 625, 634 (Tex. App.—Austin 2000, pet.

denied). “Pooling entails the joinder of various tracts of land sufficient for the issuance

of a permit to drill a well in accordance with applicable spacing rules.” MCZ, Inc. v.

Triolo, 708 S.W.2d 49, 52 (Tex. App.—Houston [1st Dist.] 1986, writ ref’d n.r.e.). “The

primary legal consequence of pooling is that production and operations anywhere on

                                            20
the pooled unit are treated as if they have taken place on each tract within the unit.”

Samson Expl., LLC v. T.S. Reed Props., Inc., 521 S.W.3d 766, 774–75 (Tex. 2017)

(quoting Pipe Line Co. v. Tichacek, 997 S.W.2d 166, 170 (Tex. 1999)).

       Texas has adopted the view “that pooling effects a cross-conveyance among

the owners of minerals under the various tracts of royalty or minerals in a pool so that

they all own undivided interests under the unitized tract in the proportion their

contribution bears to the unitized tract.” Montgomery v. Rittersbacher, 424 S.W.2d 210,

213 (Tex. 1968). Because pooling affects royalty interests, an executive lacks the

power to bind an NPRI to a pooling provision absent the NPRI owner’s consent. Id.;

see Samson Expl., LLC, 521 S.W.3d at 775. Consent may be given by, among other

things, signing a pooling agreement or ratifying an oil and gas lease containing a

pooling provision. See Samson Expl., LLC, 521 S.W.3d at 775; Montgomery, 424

S.W.2d at 215; MCZ, Inc., 708 S.W.2d at 53.

       Generally, “[r]atification of an oil and gas lease by [NPRI owners] is only

necessary to effect a pooling of production, and such ratification has been construed

as an offer made by the lessor, and accepted by the royalty owners to apportion all

proceeds from the lease.” Verble v. Coffman, 680 S.W.2d 69, 70 (Tex. App.—Austin

1984, no writ); see London v. Merriman, 756 S.W.2d 736, 739 (Tex. App.—Corpus

Christi–Edinburg 1988, writ denied) (“Absent consent, the executive does not have the

legal right to authorize the lessee to pool the royalty rights of the [NPRI] owner with

other royalty interest owners. A lease which purports to do so is essentially an offer by

the lessor to the other royalty interest owners to create a community lease by ratifying

                                           21
the lease; if they do ratify it, the lease effects a cross-conveyance of interests and a

pooling or combining of royalty interests.”) (internal citations omitted). If an NPRI owner

refuses to consent to pooling, as is its right, “an NPRI must be paid on a nonpooled

basis while pooled interests share pro rata.” Samson Expl., LLC, 521 S.W.3d at 775.

“Thus a lessee may owe different royalty obligations with respect to the same lands.”

Id.

B.     Analysis

       As an NPRI owner, Kenneth had no executive rights and thus no ability to enter

into a lease with Conoco. See Plainsman Trading Co., 898 S.W.2d at 789. Kenneth’s

only interest in the Conoco/Gips Lease is his fixed one-eighth NPRI. Consequently,

absent a provision in the lease purporting to affect Kenneth’s interest, there was no

reason for Conoco to seek Kenneth’s ratification of the lease. Montgomery, 424 S.W.2d

at 211–12; Verble, 680 S.W.2d at 70. But the lease does include a pooling provision,

and, as noted, pooling effects a cross-conveyance of mineral and royalty interests.

Montgomery, 424 S.W.2d at 213. By entering into a lease containing a pooling

provision with Conoco, the Gipses extended an offer to the royalty interest owners in

Tract A to pool their interests. See Verble, 680 S.W.2d at 70; London, 756 S.W.2d at

739. Kenneth ratified the lease and, by doing so, agreed to have his fixed one-eighth

NPRI subject to Tract A’s tract participation rate in Maurer Unit B—and nothing more.

       The case law of ratification in the pooling context guides that determination. In

Ruiz v. Martin, for example, appellees owned a one-half NPRI in a 463.8-acre tract,

which the parties called Tract I. 559 S.W.2d 839, 840–41 (Tex. App.—San Antonio

                                            22
1977, writ ref’d n.r.e.). Appellant owned three tracts—Tracts I–III—totaling 600 acres.

Id. at 840. Appellant entered into an oil and gas lease covering the full 600 acres. Id.

at 841. The lease contained, among other things, a one-eighth landowner’s royalty

clause and a pooling clause. Id. Appellees ratified the lease “to the same extent as if

they had originally joined in the execution thereof.” Id. A gas well was subsequently

established on Tract II. Id. at 840. “Appellant asserted that he was entitled to all of the

royalties from gas produced from such well, and appellees asserted that they had an

interest in such royalties.” Id. The gas company brought suit “seeking a determination

of the ownership of the royalties accruing” from the gas well. Id. The trial court held

that appellees were entitled to a decimal royalty rate of 0.3865, representing their one-

half NPRI in Tract I multiplied by Tract I’s tract participation factor in the pooled unit

(463.8 acres divided by 600 acres). Id. In other words, appellees were due their full

one-half NPRI diminished only by the tract participation factor, even though no

production was occurring on Tract I. The court of appeals affirmed. Id. at 844. By

ratifying the oil and gas lease “to the same extent as if they had originally joined in the

execution thereof,” appellees were entitled to pooled royalties but were not thereby

bound by the one-eighth landowner’s royalty provision—a provision that did not purport

to affect their interest. See id.; see also Montgomery, 424 S.W.2d at 215 (“[W]e hold

that the [NPRI] owner has the option to ratify or repudiate a lease containing provisions

which as to his interest the holder of the executive rights had no authority to insert in

the lease.”); Brown v. Smith, 174 S.W.2d 43, 46 (Tex. 1943) (“Had Mrs. Lee, the owner

of the outstanding royalty interest in the 20-acre tract, joined in the execution of the oil

                                            23
and gas lease, she would have become a party to the pooling agreement contained in

the lease.”); Verble, 680 S.W.2d at 70 (ratification of an oil and gas lease “is only

necessary to effect a pooling of production, and such ratification has been construed

as an offer made by the lessor, and accepted by the royalty owners to apportion all

proceeds from the lease”); London, 756 S.W.2d at 739 (“Absent consent, the executive

does not have the legal right to authorize the lessee to pool the royalty rights of the

[NPRI] owner with other royalty interest owners. A lease which purports to do so is

essentially an offer by the lessor to the other royalty interest owners to create a

community lease by ratifying the lease.”).

       Nevertheless, Conoco argues that Kenneth may not ratify its lease with the

Gipses for pooling purposes only. Conoco cites six cases for the proposition that “a[n]

[NPRI] owner must either ratify the entire transaction or agreement, or none of it.” Only

two of the cited cases arise in the context of NPRIs: (1) Montgomery v. Rittersbacher,

cited above; and (2) Hawkins v. Texas Oil & Gas Corp., 724 S.W.2d 878, 890 (Tex.

App.—Waco 1987, writ ref’d n.r.e.). And the facts in both cases are distinguishable

from the facts here.

       In Montgomery, Montgomery was the owner of a one-half floating NPRI in an

eighty-acre tract of land, which the parties called “First Tract.” 424 S.W.2d at 211.

Rittersbacher maintained the executive interests in First Tract and a contiguous

property called “Second Tract.” Id. Montgomery held no interests in Second Tract. Id.

Rittersbacher entered into an oil and gas lease with Sun Oil Company (Sun) covering

both tracts. Id. The lease contained a pooling provision as well as an entirety clause,

                                             24
which provided that:

       If the leased premises are now or shall hereafter be owned in severalty
       or in separate tracts, the premises, nevertheless, shall be developed and
       operated as one lease, and all royalties accruing hereunder shall be
       treated as an entirety and shall be divided among and paid to such
       separate owners in the proportion that the acreage owned by each such
       separate owner bears to the entire leased acreage.

Id. at 212.

       Sun “formed several units out of the original leased acreage.” Id. Part of Second

Tract was pooled with a unit called “Crutchfield Tract,” in which neither Montgomery

nor Rittersbacher owned interests. Id. Sun drilled a well on Crutchfield Tract from which

commercial oil production began. Id. Montgomery brought suit to collect royalties from

Crutchfield Tract by virtue of the entirety clause within Sun and Rittersbacher’s lease,

which Montgomery claimed to have ratified. Id. Both First Tract and Second Tract were

subject to the oil and gas lease. According to Montgomery, since Second Tract was

pooled with Crutchfield Tract, the owner of Second Tract was to receive royalties from

production on Crutchfield Tract. And since, per the lease’s entirety clause, royalty is to

“be treated as an entirety” and paid to the separate owners in proportion to their

acreage, Montgomery sought “the proportion of the royalties accruing under the lease

that his [NPRI] bears to the leased acreage.” Id. The trial court and this Court held for

Rittersbacher. Id. at 211. Montgomery appealed to the supreme court, which reversed

in his favor. Id.

       The supreme court reiterated that it has held that “pooling effects a cross-

conveyance among the owners of minerals under the various tracts of royalty or

minerals in a pool so that they all own undivided interests under the [pooled] tract” on
                                          25
a pro rata basis. Id. at 213. It noted, therefore, that the executive may only bind the

NPRI owner to a pooling provision with the NPRI owner’s consent. Id. The supreme

court saw “no distinction between” a pooling clause and the relevant entirety clause,

insofar as they both had the effect of changing the aggregate ownership of an NPRI

owner’s interest. Id. Accordingly, it held “that the [NPRI] owner has the option to ratify

or repudiate a lease containing provisions which as to his interest the holder of the

executive rights had no authority to insert in the lease.” Id. at 215.

       The court concluded that Montgomery fully ratified Sun and Rittersbacher’s

lease by suing to collect royalties under the lease, and so he was bound by the terms

therein affecting his interests. Id. at 214–15. Having ratified the lease, Montgomery

was “as much bound thereby as if he had joined in the original execution thereof. As

long as the lease is in force, [Montgomery was] not free to claim his full 1/2 [NPRI]

under ‘First Tract.’” Id. at 215. In other words, having ratified the pooling and entirety

provisions, Montgomery could not claim his full one-half interest in First Tract, as he

agreed to royalties from First Tract, Second Tract, and Crutchfield Tract on a pooled

basis using a tract participation percentage.

       Conoco points to Montgomery’s “not free to claim his full 1/2 [NPRI]” language

to support its proposition that “if the [NPRI] owner ratifies the lease to allow pooling, he

is bound for all purposes, including by the [landowner’s] royalty provision.” But that is

unsupported by Montgomery for two reasons. First, as just noted, the quoted passage

of Montgomery merely stands for the rule that when an NPRI owner agrees to royalties

on a pooled basis, it cannot then demand royalty payments unaffected by the pooled

                                            26
tract participation factor. Second, Montgomery deals with pooling and entirety

provisions in a lease that affect an NPRI owner’s royalty interest. Id. at 213 (holding

that pooling clauses and the relevant entirety clause affect an NPRI owner’s aggregate

ownership). It does not, as Conoco suggests, have any bearing on a landowner’s

royalty provision, which does not affect Kenneth’s interest as a fixed NPRI owner. See

Hysaw, 483 S.W.3d at 9 (noting that a fixed NPRI “remains constant regardless of the

amount of royalty contained in a subsequently negotiated oil and gas lease”).

       Notably, the supreme court in Montgomery stated that “[h]ad [Rittersbacher and

Sun] not intended to include Montgomery’s [NPRI] within the provisions of the entirety

clause, they could have easily taken affirmative steps to exclude the interest from the

operations of the clause.” Id. Ostensibly, such a provision would include language

specifically excluding NPRI owners from “mak[ing] an entirety clause [or a pooling

clause] operative on [the NPRI owner’s] interests.” Id. at 214. Likewise, had Conoco

and the Gipses intended for their lease to diminish or inflate Kenneth’s interests as a

fixed NPRI owner outside the pooling context, they could have included explicit

provisions to that end in their lease which Kenneth would then choose whether to fully

ratify. But no such provision exists.

       Hawkins involved the “interpretation of a 1930 deed which conveyed oil and gas

interests under 54.2 acres ‘subject to’ a Humble oil and gas lease that ha[d] since

expired.” 724 S.W.2d at 880. The deed’s granting clause conveyed to W.S. York and

Max Scharff a fixed royalty interest in the subject property, and the future-lease clause

conveyed to each party a one-fourth mineral interest following the termination of the

                                           27
Humble lease. Id. at 882–83. The chief issue presented was whether, at the expiration

of the Humble lease, “the grantees owned a royalty interest or a mineral interest.” Id.

at 880.

       Marjorie Hawkins and Phillip Baker were the successors to Scharff’s interests

under the deed, and John and Kathryn Alford were the successors to York’s interests.

The Alfords entered a lease with Texas Oil and Gas Corporation (Texas Oil),

purportedly leasing all of the relevant tract’s mineral estate for a one-eighth

landowner’s royalty (the Alford Lease). Id. at 881. But Hawkins and Baker “refused to

accept royalty payments under th[e Alford L]ease or to ratify it because they claimed

ownership of a 1/4 mineral interest” under the 1930 deed. Id. Instead, after the dispute

over their one-fourth interest arose, they entered into their own lease with Texas Oil,

leasing their purported one-fourth mineral interest for a one-sixth landowner’s royalty.

Id. Texas Oil pooled both leases into the Williford Gas Unit, and two producing oil wells

were drilled within the Williford Gas Unit. Id. Texas Oil withheld royalty payments to

Hawkins and Baker pending resolution of the dispute over their alleged one-fourth

mineral interest. Id.

       Hawkins and Baker filed a declaratory judgment action against the Alfords and

Texas Oil to clarify what interests each party acquired and to recover royalty payments

under their lease. Id. at 880. Hawkins and Baker “claimed that the [1930] deed’s

granting clause conveyed a royalty interest, which terminated upon the expiration of

Humble’s lease, followed by a grant . . . in the future-lease clause of a 1/4 mineral

interest.” Id. Hawkins and Baker also signed affidavits attempting to ratify only the

                                           28
pooling provision within the Alford Lease. The Alfords and Texas Oil contended that a

conflict existed between the 1930 deed’s granting clause and future-lease clause and

that supreme court precedent dictated that, in such instances, the granting clause must

prevail. Id. at 880–81. Accordingly, the Alfords contended that they owned all of the

minerals under the 54.2 acre-tract, burdened only by the fixed royalty interest conveyed

in the granting clause. Id. at 881.

       The trial court concluded in relevant part that: (1) Hawkins and Baker owned a

fixed royalty interest under the deed and not a one-fourth mineral interest; and

(2) neither Hawkins nor Baker were entitled to royalties from the Alford Lease because

they did not ratify the lease. Id. at 881–82. The court of appeals affirmed on all grounds.

In their unsuccessful appeal, Hawkins and Baker again argued, among other things,

that they ratified the pooling of their royalty interests under the Alford Lease and were,

therefore, entitled to such royalties. Id. at 881. The court of appeals overruled that

argument, noting that:

       [Hawkins and Baker] attempted through affidavits to ratify one provision
       of the [Alford L]ease, the pooling provision, while repudiating the royalty
       provision and contesting the ownership of the mineral estate covered by
       the lease. Therefore, Hawkins and Baker cannot now claim the benefits
       of the [Alford L]ease which they have consistently repudiated and refused
       to ratify in its entirety.

Id.

       Conoco presents the immediately preceding quoted language in Hawkins to

support its proposition that Kenneth may not ratify the pooling provision of its lease

with the Gipses while repudiating the “royalty provision.” But the facts in Hawkins are

distinguishable. In the first place, unlike in Hawkins, only one lease is at issue in this
                                             29
case. Further, by “repudiating the royalty provision,” the court in Hawkins was referring

to Hawkins and Baker’s contention that they were owed a one-sixth landowner’s royalty

from their lease rather than a fixed royalty interest from the Alford Lease. By “contesting

the mineral estate covered by the lease,” the court in Hawkins was referring to Hawkins

and Baker’s contention that, through the 1930 deed, they were conveyed a combined

one-fourth mineral interest in the 54.2-acre tract. It was the existence of two leases,

two theories of deeded mineral interests, and an attempted partial ratification of the

Alford Lease at issue in Hawkins. No such disputes exist in the instant case. Here, it is

undisputed that Kenneth ratified the Conoco/Gips Lease in its entirety, and that the

landowner’s royalty rate due to the Gipses is one-fourth. And unlike in Hawkins,

Kenneth is not claiming entitlement to a landowner’s royalty at all, or one in excess of

the Gipses’. As Kenneth highlights, the most relevant holding in Hawkins may be its

reiteration that a fixed NPRI is not diminishable by a landowner’s royalty. See id. at

889. Conoco provides no other relevant authority which would lead this Court to stray

from the general rule that by ratifying a typical oil and gas lease, an NPRI owner merely

agrees to have its interests pooled per the lease’s pooling provision.

       By its citation to general ratification principles, Conoco apparently argues that

ratification of a pooling provision can only benefit an NPRI owner. See Land Title Co.

of Dall., 609 S.W.2d at 757 (“A principal may not, in equity, ratify those parts of the

transaction which are beneficial and disavow those which are detrimental”). But by

agreeing to have its interest pooled, an NPRI owner generally accepts both the benefits

and the burdens of pooling. An NPRI owner benefits from an off-tract well by

                                            30
entitlement to royalties it would otherwise not obtain. An NPRI owner’s interests are

burdened, however, when a well is drilled on its tract, as the NPRI owner must share

the royalties on a pooled basis that it would otherwise enjoy at its full value. See

Mengden v. Peninsula Prod. Co., 544 S.W.2d 643, 648 (Tex. 1976) (“When a unit is

properly pooled, the owners of the minerals or reversionary interests in a separate tract

within the unit surrender their right to receive their interest in all production from wells

located on their own tract, and in turn they receive the right to share proportionately

from wells on the other included tract.”). While some courts in Texas have allowed

NPRI owners to selectively ratify pooling arrangements of benefit, see, e.g., MCZ, Inc.,

708 S.W.2d at 54–55, in this case, Kenneth ratified the pooling provision before any

well was drilled within the pooled Maurer Unit B. In other words, Kenneth had no

knowledge as to whether production would occur on Tract A or on other tracts in the

pooled unit. Kenneth thus accepted both the benefits and the burdens of the pooling

clause—the only provision in the Conoco/Gips Lease that purports to affect his

interests.

       Finally, not only is Conoco’s argument that Kenneth cannot simply ratify the

pooling provision in its lease contrary to the case law on point, but it is also not

sufficiently developed. For instance, Conoco argues that Kenneth cannot selectively

ratify its lease with the Gipses, but then only argues that Kenneth should be bound to

the lease’s pooling and landowner’s royalty provisions. However, under Conoco’s

rationale that Kenneth should be bound to all terms in the lease “as if [Kenneth] had

originally been named as Lessor in the Lease,” ostensibly, Kenneth should receive all

                                            31
of the benefits and entitlements due to the Gipses as lessors under the lease as

provided in the lease’s other various provisions. 6 But that result is obviously unsound.

As an NPRI owner, Kenneth has no executive rights and is, therefore, due none of the

entitlements owed to the lessor under the lease. See Plainsman Trading Co., 898

S.W.2d at 789. Likewise, as a non-executive, Kenneth is not entitled to a landowner’s

royalty. Id. Conoco has not fully addressed the practical consequences of its argument.

        In sum, the relevant case law specific to NPRI ratification guides our conclusion

that the effect of Kenneth’s ratification of the Conoco/Gips Lease was only to bind him

to the lease’s pooling provision—the only reason Conoco and the Gipses would require

Kenneth’s ratification of their lease. See Montgomery, 424 S.W.2d at 211–12; Verble,

680 S.W.2d at 70. We do not hold that an NPRI holder may never diminish its rights

by ratifying an oil and gas lease with provisions explicitly purporting to do so. Leases

with such provisions may arise, and any potential appeal in such a case would present

an opportunity to address that issue. But the Conoco/Gips Lease contains no such

provision.

        Consequently, Kenneth is due his fixed one-eighth royalties from production on

Tract A from June 9, 2002, through June 8, 2017. Because Tract A was pooled into

         6 For example, the lessor under Conoco and the Gipses’ lease is entitled to, among other things:

(1) receive $1.50 per foot for a pipeline right of way for installing infrastructure; (2) receive notice from
Conoco of any suspected environmental contamination or pollution; (3) keep all of Conoco’s equipment
should it fail to remove its property within six months after the expiration of the lease; (4) require Conoco
to bury all pipe lines; (5) receive compensation for loss or damage to crops, trees, livestock, among
other things; (6) require Conoco to construct livestock fencing and to clean up trash; (7) receive $1,000
as liquidated damages for any oak tree damaged by Conoco; (8) receive $25 per day as liquidated
damages should Conoco fail to furnish a release from the oil and gas lease within sixty days of the
lease’s expiration; and (9) receive a minimum of $60 per leased mineral acre.
                                                    32
Maurer Unit B, Kenneth’s royalty interest in and to production from Maurer Unit B is

0.01507352 from first production through June 8, 2017—amounting to Kenneth’s one-

eighth NPRI diminished only by Tract A’s 0.12058814 pooling participation rate.

       We sustain Kenneth’s first issue.

                                VI.    ATTORNEY’S FEES

       By his second issue, Kenneth argues that “the trial court err[ed] in awarding

attorney’s fees to Conoco[] under the [UDJA].” We agree.

A.     Applicable Law

       The UDJA provides that:

       A person interested under a deed, will, written contract, or other writings
       constituting a contract or whose rights, status, or other legal relations are
       affected by a statute, municipal ordinance, contract, or franchise may
       have determined any question of construction or validity arising under
       the instrument, statute, ordinance, contract, or franchise and obtain a
       declaration of rights, status, or other legal relations thereunder.

TEX. CIV. PRAC. & REM. CODE ANN. § 37.004(a). Section 37.002 states that the UDJA is

intended to be remedial and “its purpose is to settle and to afford relief from uncertainty

and insecurity with respect to rights, status, and other legal relations; and it is to be

liberally construed and administered.” Id. § 37.002(b). A trial court may award costs

and reasonable attorney’s fees in a declaratory judgment action when doing so is

equitable and just. Id. § 37.009. Because the UDJA does not require an award of

attorney’s fees, on appeal, we review the trial court’s judgment awarding fees for an

abuse of discretion. Bocquet v. Herring, 972 S.W.2d 19, 20 (Tex. 1998). A trial court

abuses its discretion “when it acts arbitrarily, unreasonably, or without reference to

legal principles.” Berkel & Co. Contractors, Inc. v. Lee, 612 S.W.3d 280, 287 (Tex.
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2020).

         Declaratory relief is unavailable to settle a dispute that is currently pending

before a court. BHP Petroleum Co., v. Millard, 800 S.W.2d 838, 841 (Tex. 1990) (orig.

proceeding); Tex. Liquor Control Bd. v. Canyon Creek Land Corp., 456 S.W.2d 891,

895 (Tex. 1970) (“[A]n action for declaratory judgment will not be entertained if there is

pending, at the time it is filed, another action or proceeding between the same parties

and in which may be adjudicated the issues involved in the declaratory action.”).

However, a court may allow a declaratory judgment counterclaim when it “has greater

ramifications than the original suit.” Winslow v. Acker, 781 S.W.2d 322, 328 (Tex.

App.—San Antonio 1989, writ denied); see HECI Expl. Co. v. Clajon Gas Co., 843

S.W.2d 622, 638 (Tex. App.—Austin 1992, writ denied) (“A party bringing a

counterclaim may recover attorney’s fees under the [UDJA] if its counterclaim is more

than a mere denial of the plaintiff’s cause of action.”). “To have ‘greater ramifications’

than the original suit, the counterclaim should seek some sort of affirmative relief.”

HECI Expl. Co., 843 S.W.2d at 638–39. “To qualify as a claim for affirmative relief, a

defensive pleading must allege that the defendant has a cause of action, independent

of the plaintiff’s claim, on which he could recover benefits, compensation or relief, even

though the plaintiff may abandon his cause of action or fail to establish it.” Gen. Land

Off. of State of Tex. v. OXY U.S.A., Inc., 789 S.W.2d 569, 570 (Tex. 1990) (quoting

Weaver v. Jock, 717 S.W.2d 654, 657 (Tex. App.—Waco 1986, writ ref’d n.r.e.)).

B.       Analysis

         In this Court’s 2018 decision, we held that Kenneth reserved a fixed one-eighth

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NPRI in Tract A; i.e., Kenneth was due one-eighth of all proceeds from production from

Tract A. Hahn, 2018 WL 771908, at *8. On remand, the parties evidently agreed that

Kenneth’s interest and royalty payments were to be diminished by the pooling provision

within the Conoco/Gips Lease and that Tract A’s tract participation rate is 0.12058814.

Conoco “paid [Kenneth] for the royalties due on Tract A from the creation of the Maurer

Unit B until June 15, 2017[,] using” a royalty rate that was further diminished by the

landowner’s royalty. Kenneth filed his Fourth Amended Petition, in which he asserted

claims for statutory underpayment “of his rightful share of proceeds from the sale of oil

and gas allocable to Tract A and Tract B.” In response, Conoco filed its answer,

affirmative defenses, and declaratory judgment counterclaim noting that “[t]here is a

live dispute and controversy between the parties regarding the proper calculation of

the royalty decimal to be used to calculate [Kenneth]’s royalty share on his reserved

interest.” Conoco requested that the trial court declare Kenneth’s royalty decimal rate

to be 0.00376838 given Kenneth’s ratification of its oil and gas lease with the Gipses.

In other words, in response to Kenneth’s argument that he was being underpaid for his

share of royalties, Conoco raised Kenneth’s ratification to argue that Kenneth was not

being underpaid for his share of royalties. While such an argument would have been

properly raised as an affirmative defense, it was not properly brought as a UDJA

counterclaim. See Samson Expl., LLC, 521 S.W.3d at 781, 783 (ratification is an

affirmative defense); Land Title Co. of Dall., 609 S.W.2d at 756 (“Ratification is . . . an

affirmative defense.”); BHP Petroleum Co., 800 S.W.2d at 841 (declaratory relief not

available to settle a pending dispute). The dispute over Kenneth’s mineral royalty

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calculation already before the trial court, Conoco’s declaratory judgment action was

improper, having no ramifications beyond resolution of that very issue. See BHP

Petroleum Co., 800 S.W.2d at 841; Gen. Land Off. of State of Tex., 789 S.W.2d at 570;

HECI Expl. Co., 843 S.W.2d at 638–39. The trial court thus erred by awarding

attorney’s fees to Conoco under the UDJA. Accordingly, we sustain Kenneth’s second

issue and reverse the trial court’s award of attorney’s fees to Conoco.

      Kenneth sought attorney’s fees and costs associated with his “seeking to

enforce his rights against [Conoco] pursuant to” § 38.001 of the Texas Civil Practice &

Remedies Code and § 91.406 of the Texas Natural Resources Code. See TEX. CIV.

PRAC. & REM. CODE ANN. § 38.001; TEX. NAT. RES. CODE ANN. § 91.406. In light of our

conclusions above, we remand for a proper determination of attorney’s fees owed to

Kenneth, if any.

                                 VII.   CONCLUSION

      We (1) reverse the trial court’s judgment granting Conoco’s motion for summary

judgment, denying Kenneth’s motion for summary judgment, and awarding attorney’s

fees to Conoco, (2) render judgment that Kenneth maintained a fixed one-eighth NPRI

in Tract A and a royalty decimal interest of 0.01507352 in and to production from

Maurer Unit B from first production through June 8, 2017, and (3) remand for further

proceedings consistent with this memorandum opinion.

                                                              DORI CONTRERAS
                                                              Chief Justice

Delivered and filed on the
1st day of December, 2022.

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