EOG Resources, Inc. v. Wagner & Brown, Ltd., 202 S.W.3d 338

202 S.W.3d 338

Tex. App.

2006

OPINION

Opinion by

Justice CASTILLO.

This appeal is taken from the trial court judgment in a subsurface boundary dispute involving oil and gas interests. In competing summary judgment motions, appellee, Wagner & Brown, Ltd. (“W & B”), and appellant, EOG Resources, Inc. (“EOG”), each sought a declaration of the proper construction of certain language defining EOG’s ownership interests in several oil and gas leases. In two issues, EOG complains of the trial court’s judgment granting W & B’s motion and denying EOG’s motion. We affirm.

J. Background

W & B is the successor in interest to Longhorn Oil and Gas Company (“Longhorn”). EOG is the successor in interest to REH Energy, Inc. (“REH”).

In 1984, Longhorn owned rights in two oil and gas leases, each pertaining to minerals lying under a 388.6 acre unit near Corpus Christi International Airport. Longhorn wanted REH to explore this prospect, and executed a Farmout Agreement by which REH could earn an assignment of a portion of Longhorn’s interests in the leases. To acquire the rights, REH’s obligations included drilling a test well according to Longhorn’s specifications and drilling and completing a producing well (or plugging and abandoning if a dry hole). The relevant portion of the Farm-out Agreement relating to the transfer of rights provides:

The Assignment provided for above shall be limited in depth to 100 feet below the deepest producing interval as obtained in the test well, shall be without warranty either express or implied and shall reserve to Longhorn all rights below the assigned depths, together with such rights as are necessary to Longhorn’s full enjoyment of the reserved deeper rights. (Emphasis added)

The Farmout Agreement was designed to establish a horizontal subsurface boundary below which Longhorn’s mineral rights were located, and above which REH’s mineral rights were located.

REH drilled a successful test well, complied with all of Longhorn’s specifications, and earned an assignment of the interest in the leases as provided in the Farmout Agreement. It is undisputed that the test well (“Well # 1”) produced at depths between 9,679 feet and 9,729 feet.

No dispute arose until 2002, subsequent to Longhorn’s acquisition by W & B and REH’s acquisition by EOG, when EOG sought to drill a second well. In doing title research, EOG discovered two unrecorded assignments from Longhorn to REH dated in 1985, which altered - the boundary line set out in the Farmout Agreement. The 1985 assignments conveyed REH’s rights to “the vertical interval from the surface to the depth of 9,779 feet subsurface.”

The parties negotiated to resolve the non-conforming language, which each agreed needed to be corrected. On September 11, 2002, the parties executed the Correction of Assignments of Oil and Gas Leases and Recognition of Reversionary Interests (“Correction Assignment”). In keeping with the original Farmout Agreement, the Correction Assignment changed the language from the two 1985 assignments regarding the depth limitation back to “100 feet below the deepest producing interval as obtained in the test well.” The parties, however, dispute the construction of this phrase.

EOG contends that the language “deepest producing interval,” as used in the Farmout Agreement and the Correction Assignment, refers to the formation from which Well # 1 first established production, at whatever depth such interval is found. According to EOG, Well # l’s deepest producing interval is in the subsurface geologic formation known as the Morris Sand. In October of 2002, EOG drilled Well # 2 (2,800 feet to the north of Well # 1) into the Morris Sand, where it began producing. However, Well # 2 produced at depths between 10,280 feet and 10,266 feet, most likely because of geological faulting and a structural dip in the Morris Sand formation. Since Well # 1 produced from an entire underground formation, EOG contends its interests follow the formation to its deepest part, plus 100 feet. Such a construction necessarily means that the depth limitation is a variable number.

W & B provides additional details. Specifically, on May 7, 2002, W & B received from EOG a proposed Authorization for Expenditure (“AFE”) regarding the drilling of Well #2. W & B elected to participate in the proposed well, and timely executed and returned the AFE which implicitly provided that W & B’s ownership interest was that below the depth of 9,779 feet. 1 Only after execution of the AFE did the parties confer to resolve discrepancies regarding depth of the boundary as set out in the 1985 assignments and the Farmout Agreement. 2

Negotiations culminated in the execution of the Correction Assignment on September 11, 2002. 3 It adopts language identical to that in the Farmout Agreement, specifically identifies the test well, and puts numbers on the range of the “producing interval.” Specifically, EOG’s interest under the Correction Assignment is defined as: “All depths from the surface of the ground down to 100 feet below the deepest producing interval as obtained in the [test Well # 1] as seen at a measured depth of 9,679 feet to 9,729 feet subsurface .... ”

EOG forwarded a notice of election to participate in the completion attempt [Well # 2] to W & B on September 30, 2002. 4 W & B timely provided EOG with its intent to participate to the extent of its full interest, as set out in the earlier-executed AFE. However, on October 1, 2002, EOG forwarded to W & B a second notice of election to participate which reduced W & B’s participating interest, allegedly because W & B had executed the Correction Assignment. W & B’s interest, originally recognized as 18.3601389%, was reduced to 3.672069%.

This dispute ensued. On November 4, 2002, W & B filed suit for a declaratory judgment of the proper construction of the Farmout Agreement and the Correction Assignment. W & B also sought attorney fees. The parties filed competing motions for summary judgment, urging the court to declare their respective interpretations of the phrase “deepest producing interval as obtained in the test well.” On February 11, 2005, the trial court issued its Final Judgment, granting W & B’s motion for summary judgment, denying EOG’s motion, and declaring that the Correction Assignment “did not enlarge or alter the rights owned by the parties and that the interest of EOG Resources, Inc. under such Correction Assignment is limited to those depths lying between the surface and a subsurface depth of 9,829 feet in the properties covered thereby.” The Final Judgment identifies W & B’s working interest as an undivided 18.3601389% in the leases below a subsurface depth of 9,829 feet, and an undivided 3.672069% interest above that depth. Damages are awarded in the amount stipulated by the parties. No prejudgment interest is awarded, and the trial court declined to award attorney fees to any party. This appeal ensued.

II. Issues on Appeal

EOG urges on appeal that granting summary judgment in favor of W & B and denying summary judgment in favor of EOG was in error (issue two) because when the parties executed the Correction Assignment, they intended the phrase “deepest producing interval” to refer to an entire formation rather than a particular vertical depth (issue one).

By cross-points, W & B contends the underlying declaration should be affirmed, but that portion of the judgment declining to award attorney fees should be reversed and rendered to award W & B fees; alternatively, at the least it should be reversed and remanded for determination of the amount of a reasonable fee award.

III. Standard of Review

Suits for declaratory judgment are intended to determine the rights of parties when a controversy has arisen, before any wrong actually has been committed. Montemayor v. City of San Antonio Fire Dep’t, 985 S.W.2d 549, 551 (Tex.App.San Antonio 1998, pet. denied). We review declaratory judgments under the same standards as other judgments and decrees. Tex. Civ. Prac. & Rem.Code Ann. § 37.010 (Vernon 1997); Gutheny v. Taylor, 112 S.W.3d 715, 720 (Tex.App.Houston [14th Dist.] 2003, no pet.); Roberts v. Squyres, 4 S.W.3d 485, 488 (Tex.App.-Beaumont 1999, pet. denied). We look to the procedure used to resolve the issue at trial to determine the standard of review on appeal. Guthery, 112 S.W.3d at 720; Roberts, 4 S.W.3d at 488.

Here, the trial court determined the declaratory judgment issue through summary judgment proceedings. The function of summary judgment is to eliminate patently unmeritorious claims and defenses, not to deprive litigants of the right to a Mai by jury. Tex. Dep’t of Parks & Wildlife v. Miranda, 133 S.W.3d 217, 228 (Tex.2004) (citing Casso v. Brand, 776 S.W.2d 551, 556 (Tex.1989)); Alaniz v. Hoyt, 105 S.W.3d 330, 344 (Tex.App.-Corpus Christi 2003, no pet.). We review de novo a trial court’s grant or denial of a traditional motion for summary judgment. 5 Creditwatch, Inc. v. Jackson, 157 S.W.3d 814, 816 n. 7 (Tex.2005) (citing Schneider Nat’l Carriers, Inc. v. Bates, 147 S.W.3d 264, 290 n. 137 (Tex.2004)); Alaniz, 105 S.W.3d at 345. The movant bears the burden of showing that there is no genuine issue of material fact and that it is entitled to judgment as a matter of law. Tex.R. Civ. P. 166a(c); Alaniz, 105 S.W.3d at 345; Mowbray v. Avery, 76 S.W.3d 663, 690 (Tex.App.-Corpus Christi 2002, pet. denied). Where, as here, both parties move for summary judgment and the trial court grants one motion and denies the other, we review both parties’ motions for summary judgment and determine whether the trial court erred in its decision. Tex. Workers’ Comp. Comm’n v. Patient Advocates, 136 S.W.3d 643, 648 (Tex.2004); Dow Chem. Co. v. Bright, 89 S.W.3d 602, 605 (Tex.2002); Parker v. Parker, 131 S.W.3d 524, 530 (Tex.App.-Fort Worth 2004, pet. denied).

IV. Construction of an Agreement

In construing a written agreement, the primary concern of this Court is to ascertain the true intent of the parties as expressed in the instrument. Nat’l Union Fire Ins. Co. of Pittsburgh, Pa. v. CBI Indus., Inc., 907 S.W.2d 517, 520 (Tex. 1995). We give terms their plain, ordi nary, and generally accepted meaning unless the contract shows the parties used them in a technical or different sense. Heritage Res., Inc. v. NationsBank, 939 S.W.2d 118, 121 (Tex.1996) (citing Western Reserve Life Ins. Co. v. Meadows, 152 Tex. 559, 261 S.W.2d 554, 557 (1953)). If a contract is capable of more than one reasonable interpretation, it is ambiguous; if, however, the contract can be given a certain or definite legal meaning or interpretation, then it is not ambiguous and we will construe it as a matter of law. Coker v. Coker, 650 S.W.2d 391, 393 (Tex.1983); Cook Composites, Inc. v. Westlake Styrene Corp., 15 S.W.3d 124, 131 (Tex.App.-Houston [14th Dist.] 2000, pet. dism’d).

The parties’ interpretation of a contract is parol evidence, and parol evidence is not admissible to create an ambiguity. Friendswood Dev. Co. v. McDade & Co., 926 S.W.2d 280, 283 (Tex.1996); Zurich Am. Ins. Co. v. Hunt Petroleum (AEC), Inc., 157 S.W.3d 462, 465 (Tex.App.-Houston [14th Dist.] 2004, no pet.). Only after an agreement has been determined to be ambiguous can parol evidence be considered to help ascertain the parties’ true intent. McDade, 926 S.W.2d at 283; Hunt, 157 S.W.3d at 465; Mescalero Energy, Inc. v. Underwriters Indem. Gen. Agency, Inc., 56 S.W.3d 313, 319 (Tex. App.-Houston [1st Dist.] 2001, pet. denied).

This Court may conclude a contract is ambiguous, even though the parties do not so contend. Hunt, 157 S.W.3d at 465. When a contract is ambiguous, summary judgment is improper because the interpretation of the contract becomes a fact issue. Id. (citing Coker, 650 S.W.2d at 394; Cook, 15 S.W.3d at 131). In determining whether a contact is ambiguous, we look to the contract as a whole, in light of the circumstances present when the contract was executed. Sun Oil Co. (Del.) v. Madeley, 626 S.W.2d 726, 731 (Tex.1981); Hunt, 157 S.W.3d at 465; Mescalero, 56 S.W.3d at 319; see Hewlett-Packard Co. v. Benchmark Elecs., Inc., 142 S.W.3d 554, 561 (Tex.App.-Houston [14th Dist.] 2004, pet. denied) (“We construe a contract from a utilitarian standpoint, bearing in mind the particular business activity sought to be served.”). The contract may be read in light of the surrounding circumstances to determine whether an ambiguity exists. Sun Oil, 626 S.W.2d at 731-32; Cardwell v. Sicolar-Cardwell, 978 S.W.2d 722, 727 (Tex.App.-Austin 1998, pet. denied). We may “consider the commercial context of the transaction to aid in our interpretation.” Intratex Gas Co. v. Puckett, 886 S.W.2d 274, 278 (Tex.App.-El Paso 1994, no writ). This commercial context, however, is limited to the “ordinary terms, customs and usages then in effect” in the industry. See id.; Atwood v. Rodman, 365 S.W.2d 206, 216 (Tex.Civ.App.-El Paso 1962, writ ref'd n.r.e.).

[E]ven though a written contract be unambiguous on its face, parol evidence is admissible for the purpose of applying the eohtract to the subject with which it deals .... It merely permits proof of the then existing circumstances, in order to enable the court to apply the language used therein to the facts as they then existed. It can do no more than explain the doubtful relations of the instrument consistently with the relations of the parties, the subject matter of the contract, and the other incidents thereof.

Murphy v. Dilworth, 137 Tex. 32, 151 S.W.2d 1004, 1005 (1941) (citations omitted).

Here, both parties urge the contract, and in particular the phrase “deepest producing interval as obtained in the test well,” is unambiguous, although each puts forth a different construction of the phrase. The trial court, in granting summary judgment on the declaratory judg ment action, implicitly determined there was no ambiguity. See Hunt, 157 S.W.3d at 465; Coker, 650 S.W.2d at 394. Further, the trial court did not rely on extrinsic evidence in granting summary judgment to W & B when presented with cross-motions. We agree there is no ambiguity.

V. Analysis-Declaratory Judyment

The test well (Well # 1) produced from a depth between 9,679 feet and 9,729 feet subsurface. The original Farmout Agreement conveyed to EOG an interest from the surface down to “100 feet below the deepest producing interval as obtained in the test well.” The 1985 assignments expressed that interest as to “the vertical interval from the surface to the depth of 9,779 feet subsurface.” When a discrepancy between these descriptions was found, the parties negotiated the Correction Assignment, which reinstituted the language as originally set forth in the Farmout Agreement. W & B contends the Correction Assignment did nothing more than correct the 50-foot error apparent in the 1985 assignments. EOG contends, by contrast, that it clarifies that the deepest producing interval is not limited to a vertical depth below the test well, but rather follows the “producing interval” from which that well produced, at whatever depth it may be. EOG contends this “producing interval” is the formation, horizon, field, reservoir or stratigraphic layer otherwise known at the Morris Sand. Test Well # 1 did produce from the Morris Sand, which apparently takes a dip at some point in the land subject to the leases, thereby explaining the lower depth from which Well # 2 produced. EOG argues that the “deepest producing interval” attaches to the Morris Sand, rather than to the vertical shaft under Well # 1, and spends extensive time in its brief addressing how the term “deepest producing interval” is used in the industry. EOG contends that this is a case of first impression in Texas. We disagree.

We apply the plain, ordinary, and generally accepted meaning of the terms in the contract. See Heritage Res., 939 S.W.2d at 121. We do not look to what the parties contend was their intent, but rather to that intent as it was expressed in the final Correction Assignment. Nat’l Union, 907 S.W.2d at 520. Importantly, EOG ignores the qualifying language “deepest producing interval as obtained in the test well” (Emphasis added). It matters not how the term “producing interval” without such qualifying language may be applied. No additional language in the agreement indicates the parties intended to convey interests according to a variable depth, depending upon where a “producing interval” might be at any location in the lease. W & B’s interpretation is consistent with the Farmout Agreement and the 1985 assignments, which form part of the existing circumstances before us. We further note the ready availability of alternative language or terms which would have clearly expressed any intent to expand “producing interval as obtained in the test well” to encompass the depth of the entire Morris Sand formation lying under the leased property. Available terms include formation, horizon, field, reservoir or stratigraphic layer; the parties did not elect to use these terms in their agreement.

EOG cites various administrative regulations, asserting they define “producing interval” in a manner consistent with its interpretation. We conclude that, even if we were to ignore the qualifying language in the Correction Assignment, the regulations cited (1) do not so define “producing interval,” and (2) are, for the most part, directed to specific geologic conditions not present here. 6 None of the cited regulations support EOG’s argument that “producing interval” as used in the agreement with W & B should mean the entire formation or stratigraphic layer from which oil is produced. Some related regulations actually provide further evidence of alternative available terms which would clearly have made such provision, but which the parties did not use. 7

EOG also relies extensively upon Sande-fer Oil & Gas v. Duhon, 961 F.2d 1207 (5th Cir.1992). Sandefer involved the depth at which a lease would automatically terminate. Id. at 1208. The clause provided:

After expiration of the primary term, this lease will terminate automatically as to all horizons situated 100 feet below the deepest depth drilled (a) from which a well located on the land or acreage pooled therewith is producing in paying quantities ....

Id. The well was drilled to a depth of 17,609, but produced from a perforation between 17,090 and 17,200 (the “Middle Miogypsionoides Sand”). Approximately fifty feet below that formation, separated by a layer of shale, was a formation identified as the “Lower Miogyp” sand which the well shaft had pierced. Id. at 1209. The well produced from the higher formation; the trial court determined that the lease did not extend to 100 feet below the lower formation, principally because of the language the parties opted to use in their agreement. See id. We note first the distinction between the language “as to all horizons,” used in Sandefer, and “deepest producing interval as obtained in the test well,” which is in issue here. Further, as the Sandefer court noted, “[o]ne need not look very far, however, to find examples of clauses which just as clearly establish that the lessee shall retain lease rights to depths to which the lessee has merely drilled or tested, with no reference to production.” Id. at 1210. Just as in Sande-fer, “our analysis begins and ends with the text of the [assignment] provision relating to the depth from which the measurement is to be made.” Id. The Correction Assignment used clear language, specifically qualifying and tying the depth in issue to the test well. 8 We conclude that the trial court did not err in concluding that the Correction Assignment “did not enlarge or alter the rights owned by the parties and that the interest of EOG Resources, Inc. under such Correction Assignment is limited to those depths lying between the surface and a subsurface depth of 9,829 feet subsurface in the properties covered thereby.” The trial court did not err in granting summary judgment in favor of W & B and in denying EOG’s motion for summary judgment. We overrule EOG’s issues on appeal.

VI. Attorney Fees

In its petition, W & B sought attorney fees under both section 37.009 of the Declaratory Judgments Act, Tex. Civ. Prac. & Rem.Code Ann. § 37.009 (Vernon 1997), and under section 91.406 of the Texas Natural Resources Code. Tex. Nat. Res.Code ann. § 91.406 (Vernon 2001). By cross-appeal, W & B urges that the trial court erred in fading to award it attorney fees pursuant to section 91.406 of the natural resources code. Id.

The parties went forward on their motions for summary judgment as to the declaratory judgment action only. W & B’s motion for summary judgment is expressly limited to seeking a “declaratory judgment declaring the respective ownership interests” of EOG and W & B. A Stipulation and Agreement executed by the parties sets forth the amount of actual damages to be paid in the event W & B prevails, and provides for submission of both EOG’s and W & B’s claims for attorney fees by motion and affidavit, rather than by live testimony. Although the Final Judgment tendered to the court included provisions for those fees, none were awarded.

A party may recover attorney fees only if provided by statute or by contract. Gulf States Util. Co. v. Low, 79 S.W.3d 561, 567 (Tex.2002) (citing Dallas Cent. Appraisal Dist. v. Seven Inv. Co., 835 S.W.2d 75, 77 (Tex.1992)). Whether attorney fees are available under a particular statute is a question of law, which we review de novo. Jakob v. Gran Villa Townhouses Homeowners Ass’n, Inc., 149 S.W.3d 863, 867 (Tex.App.-Dallas 2004, no pet.). In a declaratory judgment proceeding, “reasonable and necessary attorneys’ fees” may be awarded as are “equitable and just.” Tex. Civ. Prac. & Rem.Code Ann. § 37.009 (Vernon 1997) (emphasis added); Allstate Ins. Co. v. Hallman, 159 S.W.3d 640, 643 (Tex.2005). However, a judge’s decision to award or not award attorney’s fees under this statute is reviewed on appeal for an abuse of discretion. Ridge Oil Co. v. Guinn Invs., Inc., 148 S.W.3d 143, 163 (Tex.2004). Moreover, W & B does not contend it is entitled to attorney fees under the declaratory judgments act.

Because the parties went forward solely on the declaratory judgment action, fees that may or may not be available under section 91.406 of the natural resources code are not in issue. The petition clearly sets out the claim for declaratory judgment with an attendant claim for attorney fees, and, as a separate and alternative cause of action, a claim under chapter 91 of the natural resources code for payment of proceeds. Tex. Nat. Res.Code Ann. § 19.401 et seq. (Vernon 2001). That cause of action and its accompanying claim for attorney fees were not before the trial court at the time the motions for summary judgment were ruled upon. The trial court ruled on the motions for summary judgment on December 16, 2003. Subsequently, on January 31, 2005, the parties entered into their Stipulation and Agreement so that a final judgment might be secured. The Final Judgment, incorporating the stipulated damages, was entered on February 11, 2005.

W & B’s cross-issues on appeal are directed solely to its entitlement to attorney fees under a statutory claim that was not before the trial court. The trial court did not err in failing to award fees on the basis of that claim. W & B’s cross-issues are overruled.

VII. Conclusion

Having overruled EOG’s issues on appeal and W & B’s cross-issues on appeal, we affirm the judgment of the trial court in all respects.

Notes

. The AFE specifically provides that W & B’s percentage working interest is 18.3601389%, rather than a reduced 3.672069%.

. There was some dispute as to when each of the parties first learned of the 1985 assignments.

. During these negotiations, each party tendered alternative proposals, each of which was rejected by the other.

. Well # 2 was completed on October 25, 2002, to a depth of between 10,230 and 10,-266 feet subsurface.

. W & B's petition includes additional alternative claims for fraudulent inducement, unjust enrichment, conversion, money had and received, and payment of proceeds pursuant to chapter 91 of the natural resources code. Tex. Nat. Res.Code Ann. § 91.401 et seq. (Vernon 2001). W & B filed a traditional motion for summary judgment on its declaratory judgment claim. EOG filed a counter motion for summary judgment on that same claim. EOG’s motion also included a no-evidence motion as to W & B’s other alternative claims. However, at the hearing, EOG made it clear that it would not address those claims, and that it was not going forward on its no-evidence summary judgment motion:

[T]he parties have agreed not to hear any of that because the Court’s ruling on the legal issue will be dispositive ..., depending on how the Court rules, of course ... so we have agreed ... that today we are only hearing and responding to the legal question of what do these contracts mean.

.Section 3.41 of title 16 of the Texas Administrative Code provides that field designations shall include "the producing intervals of all pertinent oil and gas wells," and for a discovery well, should identify "the names of the producing formations, and approximate average depth of the producing interval.” 16 Tex. Admin. Code § 3.41(a) (2006). Section 3.101(directed to certifications for severance tax exemptions) provides that such applications should include, for wells producing coal seam gas, a log including a "detailed lithologic description of the gas-producing interval,” and, for wells producing Devonian shale gas, information calculating the percentage of footage of the producing interval which is not Devonian shale and "reference to a standard stratigraphic chart of text establishing that the producing interval is a shale of Devonian age.” 16 Tex. Admin. Code § 3.101(e) (2006). Section 3.86 applies to horizontal drainhole wells, and defines a "correlative interval” as the designated depth interval for the field or "the producing interval for the field in which the horizontal drainhole is completed.” 16 Tex. Admin. Code § 3.86(a) (2006). EOG concedes in its brief that law pertaining to horizontal wells is not applicable in this case.

. Section 3.13 (dealing with casing, cementing, drilling and completion requirements for a well) defines "productive horizon” as "any stratum known to contain oil, gas or geothermal resources in commercial quantities in the area.” 16 Tex. Admin. Code § 3.13(a)(2)(D) (2006).

. We further note that Longhorn and REH executed an original Joint Operating Agreement ("JOA”) on January 18, 1984; the Farmout Agreement was executed on January 31, 1984. The parties provided in the JOA, in the context of abandonment of wells that have produced, that interests transferred to a non-abandoning party would be limited to the "interval or intervals of the formation or formations then open to production.” Clearly, the parties knew such language was available and understood its meaning, but opted to use narrower language in the Farmout Agreement. It is that same language that was carried forward into the Correction Assignment.