Opinion issued August 25, 2011.

In The

Court of Appeals

For The

First District of Texas

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NO. 01-09-00328-CV

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Samson Lone Star, Limited Partnership n/k/a Samson Lone Star L.L.C., Appellant

V.

Charles G. Hooks III, Individually and as Independent Executor of the EState of Charles G. Hooks, Jr., as Trustee of the Scott IRA McKeever Trust and the David Wayne McKeever Trust, and on behalf of Chas. G. Hooks & Son, a General Partnership;McKeever Partnership, LTD; Charles G. Hooks III and Sue Ann Hooks, as Co-Trustees under the Will of Charles G. Hooks, Sr., Appellees

On Appeal from the 60th District Court

Jefferson County, Texas

Trial Court Case No. B173008-B[1]

O P I N I O N

          This is an appeal from a final judgment against appellant Samson Lone Star, Limited Partnership n/k/a Samson Lone Star L.L.C. (“Samson”) for more than $21 million in favor of appellees Charles G. Hooks, et al. (“the Hooks”).  Samson has a number of oil and gas leases from landowners in Hardin and Jefferson Counties.  The judgment arises from an oil and gas case in which the Hooks brought suit against Samson with respect to three oil and gas leases, two in Hardin County, Texas (the “95-acre Lease” and the “10-acre Lease,” collectively the “Hardin County Leases”) and one in Jefferson County, Texas (the “Jefferson County Lease”). The Hooks sued Samson for breach of contract, fraud, fraudulent concealment, statutory fraud, negligent misrepresentation, violation of the Texas Natural Resources Code for failure to properly pay royalties, statutory negligence, common law negligence per se, injunctive relief, and declaratory judgment.  The trial court granted Samson’s motion for partial summary judgment on whether it had breached certain offset obligations under the leases.  It also granted the Hooks’ motions for summary judgment on claims for additional royalties related to their claims of “unpooling” with respect to the Hardin County Leases and breach of the “most favored nations” clause in both Hardin County Leases and the Jefferson County Lease. 

          The questions of whether Samson committed fraud against the Hooks with respect to a well drilled within the buffer zone of the Hooks’ Jefferson County Lease and whether it underpaid royalties by not paying royalties for “formation production” in all three Leases were tried to a jury.  The trial court rendered judgment on the verdict, holding Samson liable to the Hooks for fraud and underpaid royalties, and it entered a final judgment that left intact the summary judgment in Samson’s favor on offset obligations and the summary judgments in favor of the Hooks on their unpooling claim and their most favored nations clause claims.  Samson has appealed the final judgment and the Hooks have cross-appealed. 

In eight issues, Samson complains that (1) there is legally and factually insufficient evidence of common law fraud; (2) there is legally and factually insufficient evidence of statutory fraud; (3) the statute of limitations bars the Hooks’ fraud claims; (4) there is legally and factually insufficient evidence to support the jury’s finding on fraud damages; (5) the trial court erred in interpreting the phrase “formation production” in the Hooks’ Leases as requiring Samson to pay twice for molecules of gas produced as condensate; (6) the trial court erred in entering judgment in favor of the Hooks for additional royalties based on the unpooling issue with respect to the Hardin County Leases and on the most favored nations clauses in all three Leases; (7) the trial court erred in elevating lease provisions into a permanent injunction, and there is no evidence to support the injunction or attorney’s fees; and (8) the trial court erred by granting post-judgment interest at the rate of 18%, compounded annually.[2]

          In a single issue, the Hooks complain on cross-appeal that the trial court erred in rendering summary judgment in favor of Samson on the issue of whether Samson breached certain offset obligations in the Hooks’ leases. We affirm the trial court’s summary judgment order in favor of Samson on its offset obligations.

          With respect to Samson’s appeal, we reverse the final judgment of the trial court and render judgment that the Hooks take nothing.

I. SAMSON’S APPEAL

A. BACKGROUND

1.     Facts Related to the Jefferson County Lease and the BSM 1 Unit

          In 1999, the Hooks entered into the Jefferson County Lease with Samson.  This lease covered 640 acres owned by the Hooks in the Dyches survey in Jefferson County, Texas and was bordered by Pine Island Bayou, which also serves as the county line between Jefferson and Hardin Counties.  

Article VI of the Jefferson County Lease was a section called “Offset Obligations.”  In this section, Samson covenanted to operate the leased premises as a reasonably prudent operator would and to protect the leased premises from drainage.  Article VI also contained specific obligations for Samson in case of potential drainage.  This Article provided that if a gas well were completed within 1,320 feet from the leased premises, then, within 90 days from the date of the sale of first production from that well, Samson must take one of three actions: (1) drill an offset well; (2) pay the Hooks “compensatory royalties”—in addition to any royalties currently due—in a sum equal to the royalties that would be payable under the Lease on the production from the adjacent or nearby producing well if it had been producing on the leased premises; or (3) release the offset acreage.[3]  The Jefferson County Lease did not provide for pooling.

          In April 2000, Samson began drilling a gas well, the Black Stone Minerals No. 1 (the “BSM 1 well”), on a tract adjacent to the Hooks’ 640-acre Jefferson County Lease.  This adjacent tract was located in Hardin County.  The surface drillsite was outside the 1,320-foot buffer zone around the Jefferson County Lease that triggered Samson’s offset obligations under Article VI(A) of the Lease.  However, the BSM 1 was a directional well that slanted away from the surface drillsite.  Originally, the well was planned with a bottom hole location 1,080 feet from the Hooks’ lease line, a location within the 1,320-foot buffer zone.  This proposed well location was reflected on a plat titled “Proposed Well Location [BSM]1 Walker Pettitt League, A-43, Hardin County, Texas,” which was prepared and signed by a third-party surveyor on March 22, 2000.  The surveyor certified that “this is a true and correct plat based on a ground survey made under my supervision on March 22, 2000.”  This plat was filed with the Railroad Commission of Texas (“Railroad Commission”).

          The March 22, 2000 plat showed a 704.00 acre gas pooling unit designated by Samson that ran along Pine Island Bayou, the Jefferson County line, on the east. This line was also the western boundary of the tract containing the Hooks’ Jefferson County Lease.  The Hooks and their co-owners of the tract on which their Jefferson County Lease was located were not named as lessors in the table shown on the plat of the designated unit.  An arrow shown on the plat pointed to the location of the proposed bottom hole about at the beginning of a line that ran to the eastern line of the unit at Pine Island Bayou.  Notations on the plat stated:

The Proposed Surface Location is: 

630′ FSL x 1600′ FEL Survey

2750′+ Scaled FWL x 3834′ FNL Unit.

The Proposed Bottom Hole Location is: 

330′ FSL x 330′ FEL Survey

870′+ Scaled FSL x 1080′+ Scaled′ FEL Unit.

It is undisputed that “FSL” meant “From the Southern Line” of the Walker Pettitt Survey, “FNL” meant “From the Northern Line” of the Survey, and “FEL” meant “From the Eastern Line” of the Survey, which was the Jefferson County line at Pine Island Bayou.  Thus, in this notation, the surface location of the BSM 1 well was 1,600 feet from the eastern line of the survey, and the proposed bottom hole location was about 1,080 feet from the eastern line, which marked the western line of the Hooks’ Jefferson County Lease.  The proposed bottom hole was therefore within the 1,320-foot buffer zone for the Hooks’ Lease.

Although the March 22, 2000 plat of the designated BSM 1 unit estimated the location of the proposed bottom hole location of the BSM 1 well, the exact bottom hole location of the well, following drilling, could only be ascertained from a directional survey.  This survey was completed in July 2000 and was also filed with the Railroad Commission.  Both parties agree that the survey showed the BSM 1 well to be bottomed 1,184 feet from the Jefferson County Lease, within the 1,320-foot buffer.

The BSM 1 well was completed in August 2000, and the first gas sales occurred in late October 2000.  Because the bottom hole of the well was within the 1,320-foot buffer zone of the Jefferson County Lease, the first gas sales triggered Samson’s offset obligations under the terms of the Lease.  The Hooks complain, and the jury found, however, that Samson did not follow the provisions in Article VI(A) of the Hooks’ Lease which provided that, within 90 days of the first sale of gas from a well within its buffer zone, Samson must drill an offset well, pay the Hooks compensatory royalties, or release the offset acreage.  Instead, the jury found that Samson attempted to avoid those obligations by seeking to pool the Hooks’ interest with those of other mineral owners despite the lack of pooling authority in the Jefferson County Lease while concealing the bottom hole location of the BSM 1 well.

In December 2000, Samson filed a P-12 “Pooling Authority” form with the Railroad Commission that reflected an amended pooling unit.  By letter, Samson informed the Commission that a portion of the 704 acres in the original BSM 1 unit was to be put into a separate 308.41-acre pooling unit for the proposed Black Stone Minerals No. A-1 well (“BSM A-1 well”).  Attached to the letter was a “Certificate of Pooling Authority,” which represented the Broussard tract, on which the Jefferson County Lease lay, as one of the tracts whose mineral-rights owners either had given Samson pooling authority under an instrument currently in effect or had pooled their interests into the amended BSM 1 unit.  Also attached was a plat of a revised 704-acre pooling unit dated November 16, 2000 and certified by Samson’s land man, Glenn Lanoue. 

The arrows pointing to the surface and bottom hole locations on the November 16 plat of the redesignated BSM 1 unit were the same as those pointing to the proposed surface and bottom hole locations on the original March 22, 2000 plat of the unit.  However, the acreage of the unit had been changed to show a different 704-acre BSM 1 unit from that originally filed with the Railroad Commission.  This unit, unlike the previously designated BSM 1 unit, extended beyond the eastern line of Pine Island Bayou into Jefferson County. The certificate, signed by Lanoue, stated that “this is a true and correct plat based on the best of my knowledge November 16, 2000.” 

On February 15, 2001, Samson sent the Hooks a letter offering to pool 50 acres covered by the Hooks’ Jefferson County Lease into the redesignated gas pooling unit for the BSM 1 well.  Attached to the letter was a copy of the revised plat Samson had filed with the Railroad Commission in December 2000.

On February 20, 2001, before accepting Samson’s offer to pool—which would require amendment of Article VI of the Jefferson County Lease to permit pooling—Charles Hooks, an attorney who had participated in a number of oil and gas deals, called Lanoue and sought more information. Charles Hooks inquired about the well’s location and about how his property fit in the unit.  Lanoue told him that the well was about 1,500 feet away from Pine Island Bayou, the boundary between Hardin and Jefferson Counties and the western line of the Hooks’ Jefferson County Lease.  Hooks requested a plat showing where his acreage would lie within the proposed configuration of the unit.  

That same day, Lanoue sent Hooks the same scaled plat of the redesignated pooling unit that Samson had filed with the Railroad Commission in December 2000, except that this version highlighted the configuration of the Hooks’ acreage on the eastern side of the lease between Pine Island Bayou and the eastern line of the reconfigured pooling unit.  This plat was certified by Lanoue as “a true and correct plat based on the best of my knowledge December 28, 2000.”

          A number of changes had been made to the original March 28, 2000 plat to reflect the redesignated BSM 1 unit.  The plat of the unit had been changed to reflect a substantially reconfigured unit with different boundaries extending further west and also further east into Jefferson County, encompassing part of the Broussard tract on the east that had not been included in the original unit designation.  The plat had been highlighted to show the location of the Hooks’ 50 acres.  East/west coordinates of the bottom hole of the BSM 1 well had been changed from those of the proposed bottom hole on the March 2000 plat.  At trial, Lanoue testified that he changed these coordinates with a ruler. 

          Like the March 2000 plat, the plat of the redesignated BSM 1 unit contained the arrow pointing to the location of the bottom hole, but it gave slightly changed coordinates.  And, instead of a line running from the proposed bottom hole location and showing +1,080 feet to the eastern line of the unit at Pine Island Bayou, the plat showed a different line to the bayou with an undesignated starting point.  It also showed an eastern border of the unit beyond the bayou and encompassing a portion of the Hooks’ Lease.  Above the line was the designation “+1400′.” An arrow stating “BHL” and giving the well coordinates pointed to a point on the line about one quarter of the way from the western starting point of the line to the eastern end of the line at the bayou.  Thus, if the designation “+1400′” were interpreted as the distance from the bottom hole to the bayou, the bottom hole of the BSM 1 well would be outside the 1,320 foot buffer zone for the Jefferson County Lease.  If the “+1400′ ” designation were interpreted as the distance from the undesignated starting point of the line to the bayou and the arrow one-quarter of the way along it were interpreted as the bottom hole location, the bottom hole of the well would be within the buffer zone of the Hooks’ Lease, triggering Samson’s offset obligations.

          In addition, the plat stated: 

The Bottom Hole Location is: 

290′ FSL x 740′ FEL Survey

500′ Scaled FNL x 1400′ + Scaled′ FEL Unit.

This language in the plat thus expressly stated that the bottom hole of the BSM 1 well was located about 1,400 feet from the eastern line of the redesignated unit, which encompassed the Hooks’ 50 acres from their Jefferson County Lease.  According to this notation, the bottom hole of the BSM 1 well was inside the buffer zone for the Hooks’ Lease. 

          Lanoue testified at trial that he added the notation that showed the bottom hole to be + 1,400 feet from the eastern line of the unit in August 2000 to reflect the newly shaped unit.  He also testified that he got the notation “740 feet from the east line and 290 feet from the south line” “from myself.”  He did not go to the directional survey which had been previously completed to determine the exact location of the bottom hole.  However, he intended the numbers to be “[a]s accurate as a land guy is using a ruler on a scaled piece of paper that might not even be to scale.” 

Hooks testified at trial that Lanoue orally told him that the well was 1,500 feet from Pine Island Bayou.  He then looked at the plat and concluded that the bottom hole location was approximately 1,400 feet west of Pine Island Bayou and thus outside the line that would have triggered the offset provisions in the Jefferson County Lease.  He made no other inquiries regarding the plat or the bottom hole of the well, and he did not check the records filed with the Railroad Commission to determine the exact location of the bottom hole.

          After making the pooling offer to the Hooks, Lanoue filed paperwork in the county’s real property records in February 2001 showing the Hooks as participating in the pool for the BSM 1 unit.  However, the Hooks did not actually consent to pool the 50 acres from the Jefferson County Lease into the BSM 1 unit until May 25, 2001, and they conditioned their assent on a formal amendment to the lease which they were to prepare and submit to Samson.  The Hooks did not prepare the formal amendment, however, and the parties never executed such an amendment.  Instead, the Hooks agreed to a division order setting out their percentage distribution of the unit’s proceeds, which stated that Samson would pay the Hooks royalties based on a stated percentage of their acreage in the unit to the entire acreage of the BSM 1 unit unless notified otherwise in writing. 

          After the Hooks agreed to be included in the BSM 1 unit, Samson sent royalty checks to them for their unit interest continuing through the time of trial, and the Hooks cashed the royalty checks.  However, the royalty checks did not include the additional compensatory royalties as calculated under the terms of Article VI of Hooks’ Lease for a well drilled within the 1,320-foot buffer zone of the Hooks’ Jefferson County Lease.

After the Hooks agreed to pool 50 acres of their Jefferson County Lease into the BSM 1 unit, Samson drilled a second well, the Joyce DuJay No. 1 well (“DuJay 1 well”), within the 1,320-foot buffer zone of the Hooks’ Jefferson County Lease.  That well was completed in January 2002 and made part of another pooling unit, the DuJay 1 unit, in which the Hooks also participated and from which they received royalties.  This well was offset by the BSM 1 unit.  Hooks testified that he was not defrauded with respect to the DuJay 1 unit.

2. Facts Related to the Hardin County Leases and the Hooks’ “Unpooling” Claim

          In addition to their Jefferson County Lease, the Hooks also owned two leases in Hardin County near the BSM 1 well, the 95-acre and 10-acre Hardin County Leases.  Unlike the Hooks’ Jefferson County Lease, these Leases did provide for pooling in terms that were essentially the same with respect to the manner and methods of pooling.

          The Hardin County Leases both contained language calling for an instrument “identifying and describing the pooled acreage” and stating that a “pooled unit shall become effective on the date such instrument or instruments are so filed for record.”  Article V(E) of the pooling provision in each Lease also stated that production from any part of a pooled unit that included the leased premises was considered production from the leased premises “regardless of whether . . . such production was secured before or after the date of this lease or the date of the instrument designating the pooled unit.”  The 95-acre Lease provided in Article V(E) as follows:

E.  Lessee [Samson], at its option, is hereby given the right and power in its discretion to pool or combine, as to any one or more formations, the land covered by this Lease or any portion of said land, insofar only as gas or gas condensate rights are concerned . . . with other land, lease or leases in the immediate vicinity thereof, except to the extent and in the manner hereinafter stipulated. With respect to any such unit so formed, Lessee shall execute in writing an instrument or instruments identifying and describing the pooled acreage, and file same for recording in the office of the County Clerk in Hardin County, Texas; and the pooled unit shall become effective on the date such instrument or instruments are so filed for record.  Notwithstanding anything hereof to the contrary, pooled units created hereunder and comprising all or part of the herein leased premises shall not exceed the maximum acreage figures permitted for all production units of oil or gas wells completed at certain depths under Article V. hereof unless the Railroad Commission of Texas or any governmental authority having and asserting jurisdiction over the subject matter thereof prescribes for the drilling or operation of a well at a regular location, or permits for the obtaining of the maximum allowable from any well to be drilled, drilling, or already drilled, larger pooled units than any of those herein permitted, then any such pooled unit may be established or enlarged to conform to the size either required of a well or permitted for the obtaining of the maximum allowable.  For any well drilled on and completed at depths beneath the surface of a tract covered by this lease there shall be no pooling with other lands, unless such tract is insufficient, due to either its lack of size or prior unitization hereunder, to comprise the maximum acreage figures permitted hereunder in which case all of said tract (95 acres more or less) or the then un-unitized portion of same shall be so pooled; and Lessee may include in such pooled unit such other acreage as may be available to comprise the maximum acreage figures permitted under the terms of this lease.  For a well drilled on or completed at depths beneath the surface of lands other than the herein leased premises, not less than all (100%) of the lands (95 acres more or less) or the then un-unitized portion of same shall be so pooled; and Lessee may include in such pooled unit such other acreage as may be available to comprise the maximum acreage figures permitted under the terms of this lease.

Operations for drilling on or production of gas from any part of the pooled unit which includes all or a portion of the Leased Premises, regardless of whether such operations for drilling were commenced or such production was secured before or after the date of this lease or the date of the instrument designating the pooled unit, shall be considered as operations for drilling on or production of gas from the Leased Premises, whether or not the well or wells be located on the Leased Premises, and the entire acreage constituting such unit or units shall be treated for all purposes, except the payment of royalties on production from the pooled unit, as if the same were included in this Lease. The above right and power to pool may be exercised at any time and from time to time and before or after a well has been drilled, or while a well is being drilled.  Lessee may vacate any unit formed by it hereunder by instrument in writing filed for record in said county at any time when there is no unitized substance being produced from such unit. The pooling for gas hereunder by Lessee shall also pool and unitize all liquid gas, and the royalty interest payable to Lessor thereon shall be computed the same as on gas.  For the purpose of computing the royalties to which owners of royalties shall be entitled on production from each production unit, there shall be allocated to the applicable separate tract acreage included in such production unit a pro rata portion of the production produced from such production unit.  Such allocation shall be on an acreage basis; that is to say, there shall be allocated to the applicable separate tract acreage within the unit that pro rata portion of the production produced from the production unit which the number of surface acres covered by such separate tract and included in the production unit bears to the total number of surface acres included in the production unit, commencing with the date of first production from the production unit.

(Emphasis added.)

          Early in 2001, Samson drilled the BSM A-1 well on Samson’s own lease in Hardin County.  The mineral interests underlying this lease were owned 87.5% by Black Stone Minerals and 12.5% by FirnBank as cotenants.

          Samson did not have the contractual authority to pool under its leases with either Black Stone Minerals or FirnBank.  Samson therefore negotiated with the leaseholders for such a right and concluded that both of the lessors were in agreement.  Accordingly, on March 12, 2001, Samson filed a Unit Designation for a 704-acre unit called the Black Stone Minerals “A” No. 1 Gas Unit (the “BSM A-1 unit”).  This unit designation unitized the Black Stone Minerals/FirnBank lease, as well as the Hooks’ 10-acre and 95-acre Hardin County Leases and other tracts, including leases beneath Pine Island Bayou owned by the State.  The designation reflected that it was effective as of the date of first production, and it included a list of the leases pooled, including the Hardin County Leases.  The designation for the BSM A-1 unit included gas production at all depths between 6,000 and 13,800 feet.

          FirnBank consented to be pooled into the BSM A-1 Unit in May 2001.  Samson also obtained written consent from the Hooks to pool their lease into the BSM A-1 unit.  In addition, it obtained the agreement of the Texas General Land Office and the School Land Board (collectively, the “State of Texas”), who owned adjacent land, to pool that land into the unit.  However, Black Stone Minerals, the 87.5% owner of the mineral interests underlying the drillsite, declined to consent.

          Samson drilled and completed the BSM A-1 well, and it began producing in June 2001 from the depth range of the BSM A-1 unit designated by Samson, specifically at the horizon from 12,304 to 12,332 feet.

          In December 2001, Samson finished another gas well, the DuJay 1 well.  The DuJay 1 well produced from some of the same land designated to the BSM A-1 unit, but it reached from 13,150 to 13,176 feet—lower strata than the BSM A-1 well.  The DuJay 1 well was within the area and depth limits of the BSM A-1 unit.  The DuJay 1 well began producing in January 2002.

          In February 2002, after failing to receive Black Stone Minerals’ consent to the BSM A-1 unit, Samson executed and recorded a designation for a new unit, the Joyce DuJay No. 1 Gas unit (“DuJay 1 unit”) that recited an effective date as of first production of the DuJay 1 well. Samson called the designation of the DuJay 1 well an “amendment” of the 704-acre BSM A-1 unit designation, but it designated a new, smaller, 571-acre unit with a different name, different leases, different depths and different boundaries from the BSM A-1 unit.  The DuJay 1 unit included some of the deeper strata of the originally designated BSM A-1 unit, but it excluded the horizon from which the BSM A-1 well was producing at 12,304 to 12,332 feet.  Instead, the designated DuJay 1 unit pooled its leases as to gas well production from 12,800 feet and deeper, including some already-pooled depths carved out of the BSM A-1 unit (12,400–13,800 feet) and deeper strata (below 13,800 feet).  Because of its depth limitations, the DuJay 1 unit included the DuJay 1 well, but not the shallower-completed BSM A-1 well.  The designated acreage excluded most of the Black Stone/FirnBank lease, but it included the Hooks’ Hardin County Leases and the State’s leases.

          Samson did not get consent from the Hooks to vacate or amend the BSM A-1 unit or to “unpool” their interests from the BSM A-1 unit or well.  Rather, it informed the Hooks that the BSM A-1 unit had been amended and the unit name changed.  After the BSM A-1 unit was amended, reconstituted, and renamed the DuJay 1 unit, Samson paid, and the Hooks accepted, royalty payments from pooled production from the DuJay 1 well.  Thereafter, the BSM A-1 well was produced as a lease well and was not included in any unit.  Samson did not pay the Hooks royalties on the BSM A-1 well.

          Subsequently, Samson drilled another DuJay well (the “DuJay A-1 well”) and created a separate pooling unit for that well.  The DuJay A-1 unit differed from the DuJay 1 unit by depth limitation and acreage.  The DuJay A-1 well began producing on September 25, 2002.  However, Samson did not file the DuJay A-1 unit designation until July 2003.  The Hardin County Leases were likewise pooled into the DuJay A-1 unit, and the Hooks accepted royalties on the production from that unit.

          The Hardin County Leases also contained a “most favored nation” clause.  This clause provided that, under certain circumstances, the royalties payable to the Hooks must be elevated to match the highest royalty payable to Samson’s other lessors.

3. Procedural History

In August 2004, several mineral-rights owners who had leased to Samson filed a suit against Samson styled Joyce DuJay Lee v. Samson Lone Star.  The plaintiffs, who did not include the Hooks, complained about pooling issues unrelated to the BSM 1 well.  In December 2004, other landowners, also not including the Hooks, filed a second action, styled Thomas Klorer et al. v. Samson, complaining about the same issues.  In August 2005, these two actions were consolidated. 

On his birthday in November 2006, Charles Hooks, as an oil and gas attorney, attended a seminar for oil and gas attorneys. There, he met an attorney who told him he was handling the Klorer and Lee cases against Samson. 

          On November 16, 2006, the Hooks were added to the consolidated suit in a Fifth Amended Petition.  This petition alleged against Samson various breaches of contract and common law and statutory negligence related to both the Hooks’ Jefferson County Lease and their two Hardin County Leases.  Among other things, the Hooks claimed Samson had improperly unpooled the BSM A-1 unit, and they sued to obtain all royalties they would have received from that unit as if all the lessors, including Black Stone Minerals, had agreed to pool, to be added to all royalties they received from the DuJay 1 and DuJay A-1 units (the “unpooling claim”).  The Hooks also asked for a declaratory judgment regarding the construction of the “most favored nation” clauses in their Leases, which they argued was triggered by the royalty paid to the State of Texas under a pooling agreement with Samson that was higher than the royalty due to the Hooks.  Finally, they sought the payment of royalties on “formation production” under the terms of all three Leases.  The Hooks did not, however, plead any fraud claims at that time. 

The Hooks added their fraud, fraudulent inducement, and statutory fraud claims in a Sixth Amended Petition, filed on May 7, 2007.  The Hooks alleged in the alternative (1) that their Jefferson County Lease had never been a part of the BSM 1 unit because no agreement to amend their lease to allow pooling was entered, and, therefore, they were entitled to damages under the Lease for the loss of their rights to require Samson either to drill an offset well, pay them compensatory royalties, or release their acreage, and (2) that Samson had made false representations as to the configuration of the BSM 1 unit and the location of the BSM 1 well to induce the Hooks to agree to amend the Jefferson County Lease to allow a portion of it to be pooled in the BSM 1 well and unit (the “offset obligations claim”). They contended that Samson had represented “that the [BSM 1] (gas) well was more than 1,320′ from the nearest lease line of the Hooks Jefferson County Lease” so that its offset obligations were not triggered under the Lease. The Hooks claimed that the representations were intended to save Samson from having to pay them the substantially greater compensatory royalties that would have been payable under the terms of the Lease for infringement of the 1,320-foot buffer zone.  The Hooks contended alternatively that, if their interests were pooled, they were entitled to damages at least equal to the difference between the value they would have received from Samson’s compliance with the terms of the Lease and the royalties they actually received.

In September 2007, the trial court severed the consolidated action against Samson into three different actions, one of which was the Hooks’ action against Samson for fraud and breach of contract.[4]

          Subsequently, the Hooks moved for partial summary judgment on several of their claims based on the terms of their leases.  The Hooks moved for summary judgment on the unpooling claim, claiming that Samson did not have authority to vacate the BSM A-1 unit into which their Hardin County Leases were pooled and that, therefore, Samson had breached its lease contract by failing to pay them royalties on the BSM A-1 well.  The Hooks also moved for summary judgment on their most-favored-nations claim, formation production claim, and offset claims.  They argued that Samson failed to pay them “royalties based on a greater ‘Most Favored Nations’ rate and compensatory royalties on certain offset encroaching wells.”

Samson moved for partial summary judgment on the offset obligations provision, on the formation production claims, and on the most favored nation claim. Samson also moved for summary judgment on the Hooks’ unpooling claim on the basis of limitations. 

The trial court granted the Hooks’ motion and denied Samson’s motion on the unpooling claim.  It assessed damages of $766,626.85 against Samson on the Hooks’ unpooling claim.  The trial court also granted the Hooks’ summary judgment motion on their claim for breach of the most favored nations clause in their Hardin County Leases and awarded $848,854.01 in damages.

The trial court granted Samson’s motion on the offset obligations provision and denied the Hooks’ corresponding motions.  The trial court also disposed of some other contract claims by other partial summary judgment motions. 

In 2008, the case went to trial solely on the Hooks’ fraud claims and the formation production claims.  These included the Hooks’ claims that Samson’s land man, Lanoue, had made misrepresentations to them to get them to allow Samson to add their 50 acres subject to the Jefferson County Lease to the BSM 1 pooling unit for the BSM 1 well, which was within the 1,320-foot buffer zone for the Lease. The Hooks contended Samson made these misrepresentations to avoid abiding by the terms of Article VI(A) of the Jefferson County Lease, which would have required Samson to drill an offset well, release their acreage, or pay them compensatory royalties, and, therefore, they were entitled to damages.  The Hooks also claimed that they were entitled to additional royalties under the formation production clauses in their Jefferson County and Hardin County Leases.

The jury answered “yes” to the questions of whether Samson committed fraud and statutory fraud with respect to the Hooks’ claims regarding the BSM 1 well.  It assessed damages against Samson for fraud in the amount of $20,081,638.07.  The jury further found that Samson’s failure to pay royalties based on formation production resulted in underpayment of royalties from the Hooks’ Leases.  The jury found that, in the exercise of reasonable diligence, the Hooks should have discovered Samson’s fraud by Charles “Hook’s Birthday April 2007.”  It did not respond, however, to the questions asking for a finding, by clear and convincing evidence, that the harm to the Hooks resulted from fraud or that Samson had actual awareness of the falsity of the representation or promise that the jury had found to be fraud.[5]  Therefore, it did not award exemplary damages.  The jury also did not respond to the question requesting it to “find beyond a reasonable doubt that Samson secured execution by the Hooks of a document by deception” and that the property had a value of $1,500 or more.[6]

Finally, the jury found that Samson’s failure to pay royalties based on formation production resulted in underpayment of royalties on all three of the Hooks’ Leases.

The trial court entered final judgment on the jury’s verdict, awarding the Hooks $20,081,638.07 for damages proximately caused by Samson’s fraud with respect to the BSM 1 well.  The final judgment also reaffirmed and incorporated the trial court’s previous summary judgment rulings in favor of the Hooks.  In addition to the fraud award, the judgment awarded the Hooks $766,626.85 in damages for the “unpooling” claim related to BSM A-1 well, $848,854.01 in damages for breach of the Leases’ most favored nations clause, and $52,257.22 in damages related to ad valorem taxes.  Finally, the final judgment included an award of attorney’s fees and pre- and post-judgment interest in favor of the Hooks.

4.       Claims on Appeal

Samson has appealed the judgment on the trial verdict and the partial summary judgments entered against it, and the Hooks have cross-appealed the partial summary judgments entered against them, all of which were incorporated in the final judgment. 

          Samson contends on appeal that the trial court erred in entering judgment on the jury’s finding that it committed fraud with respect to the Hooks’ Jefferson County Lease and that it withheld royalties on formation production with respect to all three of the Hooks’ claims. It also contends that the trial court erred in granting the Hooks’ motion for summary judgment on their unpooling claim with respect to the BSM A-1 well, in granting summary judgment on the Hooks’ claim for royalties under the most favored nations clause in their Jefferson and Hardin County Leases, and in denying its own motion for summary judgment on those claims.  Finally, Samson contends that the trial court erred by granting a permanent injunction in its final judgment requiring Samson to fulfill certain contract provisions on pain of contempt of court, that it erred in awarding attorney’s fees to the Hooks, and that it erred in awarding the Hooks 18% post-judgment interest compounded annually.

          The Hooks contend on cross-appeal that the trial court erred in ruling in Samson’s favor on their claims that Samson breached the “Offset Obligations” clause in the Hardin County Leases.

B. DISCUSSION

1.     The Trial Court’s Judgment on the Hooks’ Fraud Claims with Respect to the Jefferson County Lease

          In its third issue, Samson contends (1) that there is legally and factually insufficient evidence to support the jury’s finding that the Hooks could not have discovered their fraud claims until April 2007 and (2) that the statute of limitations bars the Hooks’ claim for fraud, fraudulent inducement, and statutory fraud with respect to the Jefferson County Lease.

          To prove fraud, a plaintiff must show that the defendant made (1) a material misrepresentation (2) that was either known to be false when made or was asserted without knowledge of its truth (3) which was intended to be relied upon (4) which was indeed relied upon and (5) which caused injury.  Dow Chem. Co. v. Francis, 46 S.W.3d 237, 242 (Tex. 2001).  To prove fraudulent inducement, these same elements of fraud must be established as they relate to a contract.  Coastal Bank SSB v. Chase Bank of Tex., N.A., 135 S.W.3d 840, 843 (Tex. App.—Houston [1st Dist.] 2004, no pet.). The statute of limitations for fraud is four years.  Tex. Civ. Prac. & Rem. Code Ann. § 16.004 (Vernon 2002).

“Statutes of limitations are intended to compel plaintiffs to assert their claims ‘within a reasonable period of time while the evidence is fresh in the minds of the parties and witnesses.’”  Wagner & Brown, Ltd. v. Horwood, 58 S.W.3d 732, 734 (Tex. 2001) (quoting Computer Assocs. Int’l, Inc. v. Altai, Inc., 918 S.W.2d 453, 455 (Tex. 1996)).  “As a general rule, a cause of action accrues and the statute of limitations begins to run when facts come into existence that authorize a party to seek a judicial remedy.”  Provident Life & Accident Ins. Co. v. Knott, 128 S.W.3d 211, 221 (Tex. 2003). In most circumstances, “a cause of action accrues when a wrongful act causes a legal injury, regardless of when the plaintiff learns of that injury or if all resulting damages have yet to occur.” Id.  However, the discovery rule exception to the statute of limitations operates to defer accrual of a cause of action until the plaintiff knew or, by exercising reasonable diligence, should have known of the facts giving rise to the cause of action. Computer Assocs., 918 S.W.2d at 455. 

The application of the discovery rule is permitted only in instances in which “the nature of the injury incurred is inherently undiscoverable and the evidence of injury is objectively verifiable.”  BP Am. Prod. Co. v. Marshall, 342 S.W.3d 59, 65–66 (Tex. 2011); Computer Assocs., 918 S.W.2d at 456.  “An injury is inherently undiscoverable if it is, by its nature, unlikely to be discovered within the prescribed limitations period despite due diligence.”  Wagner & Brown, 58 S.W.3d at 734–35; see Marshall, 342 S.W.3d at 66.  “The requirement of inherent undiscoverability recognizes that the discovery rule exception should be permitted only in circumstances where ‘it is difficult for the injured party to learn of the negligent act or omission.’” Computer Assocs., 918 S.W.2d at 456 (quoting Willis v. Maverick, 760 S.W.2d 642, 645 (Tex. 1988)). “Recognizing the social benefit in granting repose after a reasonable time,” the Texas Supreme Court has “described the rule as a ‘very limited exception to statutes of limitations.’”  Marshall, 342 S.W.3d at 66 (quoting Wagner & Brown, 58 S.W.3d at 734). 

The discovery rule “categorically does not apply to defer the accrual of royalty owners’ claims for underpayments” or the accrual of claims arising from a lesseee’s failure to continue good faith efforts to develop an oil and gas lease, because royalty owners can timely discover such injuries through the exercise of due diligence.  Marshall, 342 S.W.3d at 66; Wagner & Brown, 58 S.W.3d at 737.  Even when information that would have revealed the injury is not available from public records, it may nevertheless be “available from several other sources, including the lessee.”  Marshall, 342 S.W.3d at 66 (holding information disclosing lessee’s failure to continue good faith efforts to develop oil and gas lease was available from same sources recognized in HECI and Wagner & Brown, including public records); see HECI Exploration Co. v. Neel, 982 S.W.2d 881, 886 (Tex. 1998) (holding that, because several sources of information about common reservoirs and operations are available to royalty owners, including Railroad Commission records, discovery rule does not apply to claims of royalty owners for damage to common oil and gas reservoir).

The Hooks claimed, and the jury found, that in making their determination to agree to the pooling of 50 acres of their Jefferson County Lease in the BSM 1 unit, they relied solely on Lanoue’s oral statement that the BSM 1 well was about 1,500 feet from their Lease line and on Charles Hooks’ interpretation of the plat of the BSM 1 unit provided to him in response to his conversation with Lanoue on February 15, 2001.  They also contended, and the jury found, that they did not discover that the bottom hole of the BSM 1 well was within their 1,320-foot buffer zone, entitling them to additional compensation royalties, until well within the limitations period as extended by application of the discovery rule.[7]  Specifically, the Hooks claimed that they relied on Charles Hooks’ interpretation of the designation “+ 1400′” on the line on the plat of the redesignated unit drawn from an undesignated point to Pine Island Bayou as meaning that the bottom hole of the BSM 1 well was about 1,400 feet, or more than 1,320 feet, from their Lease, and, therefore, outside the buffer zone.  They did not inquire into seemingly contradictory information in that document showing an arrow pointing to the bottom hole of the BSM 1 well about one-quarter of the way along the 1,400-foot line from an undesignated point to Pine Island Bayou, the western line of their Jefferson County Lease.  Nor did they inquire into the notation that the bottom hole was about 1,400 feet “FEL unit,” i.e., from the eastern line of the reconfigured BSM 1 unit, which included 50 acres of their Jefferson County Lease. Both of these notations would indicate that the bottom hole of the BSM 1 well was clearly within the Lease’s 1,320-foot buffer zone. 

Although Charles Hooks was an oil and gas attorney and had participated in more than 100 oil and gas leases at the time of trial, and although he knew that Lanoue had certified the plat furnished to Hooks as being made on his own knowledge in December 2000, the Hooks never sought to investigate the results of the directional survey filed with the Railroad Commission in July 2000, which showed the exact location of the bottom hole.  Nor did they conduct due diligence in seeking the plat of the originally designated BSM 1 unit certified by the surveyor in March 2000, showing the proposed bottom hole of the BSM 1 well, which was likewise filed with the Railroad Commission in July 2000.  Both of these publicly available documents would have shown that the well was proposed to be and was bottomed within the 1,320-foot buffer zone of their Jefferson County Lease, triggering Samson’s obligations to them under Article VI(A) of the Lease.  Any inquiry into the records available from the lessee, Samson, or from the Railroad Commission would have shown the Hooks the actual location of the BSM 1 well’s bottom hole in February 2001, when pooling was first proposed to them.  The Hooks’ fraud claims were not filed until May 2007, more than six years later.

We conclude that, under Marshall, Wagner & Brown, and HECI, the nature of the Hooks’ injury was not inherently undiscoverable.  The discovery rule, therefore, does not apply to the Hooks’ fraud, fraudulent inducement, and statutory fraud claims.  See Marshall, 342 S.W.3d at 65–66; Wagner & Brown, 58 S.W.3d at 737; HECI Exploration Co., 982 S.W.2d at 886.  We hold that those claims are barred by limitations as a matter of law.

We sustain Samson’s third issue.

2. Summary Judgments Entered Against Samson on the Hardin County Leases

(a) Samson’s “Unpooling” of the BSM A-1 Unit

In its sixth issue, Samson challenges the trial court’s summary judgment awarding the Hooks damages on their claim for royalties from the BSM A-1 unit due to Samson’s improper unpooling of that unit.  Samson contends that because Black Stone Minerals, the 87.5% owner of the mineral rights on the drillsite tract (FirnBank being the owner of 12.5%), did not consent to pooling, the “essential purpose for forming that unit had failed” and the BSM A-1 unit as originally designated was not formed.  Thus, the amendment of the unit to exclude the non-consenting drillsite mineral owner, Black Stone Minerals, was justified.  Samson contends that after the BSM A-1 unit was amended and renamed the DuJay 1 unit, the Hooks accepted royalty payments from production on both DuJay units, which gave the Hooks a higher percentage of the production than they would have received under the BSM A-1 unit.  Samson argues that, by accepting these royalty payments, the Hooks accepted the amendment to the BSM A-1 unit.  Alternatively, it argues that if the amendment to the BSM A-1 unit was improper, the BSM A-1 unit still exists and the Hooks should have been paid in accordance with their interests in that unit, not their interest in the two DuJay units, which were improperly formed.  Finally, it argues that, if the BSM A-1 unit still exists, the extent of the unit must be limited to FirnBank’s 12.5% interest in the drillsite tract because only FirnBank consented to pool its undivided interest in the gas produced from the BSM A-1 well.

An oil and gas lease is a contract and is therefore interpreted as such.  Tittizer v. Union Gas Corp., 171 S.W.3d 857, 860 (Tex. 2005).   When construing a contract, the primary goal of the courts is to give effect to the parties’ written expression of their intent.  PG&E Gas Transmission v. City of Edinburg, 59 S.W.3d 225, 227 (Tex. App.—Corpus Christi 2001, no pet.).  The courts will enforce the intentions of the parties to an unambiguous oil and gas lease as expressed in the lease.  Tittizer, 171 SW.3d at 860.  In determining the agreement, the court examines all parts of the contract and the circumstances surrounding its formulation.  Columbia Gas Transmission Corp. v. New Ulm Gas, Ltd., 940 S.W.2d 587, 591 (Tex. 1996); PG&E Gas Transmission, 59 S.W.3d at 227–28.

Regulations of the Railroad Commission contain spacing requirements that limit the number of oil and gas wells and locate them in particular positions to maximize recovery.  Browning Oil Co.v. Luecke, 38 S.W.3d 625, 633 (Tex. App.—Austin 2000, pet. denied). These regulations prescribe minimum distances between a proposed well and other wells drilled in the same area and between wells and property lines.  Id.  Acreage is assigned to a well in accordance in with spacing regulations to form a drilling unit before the well may be drilled.  Id.  After the well is drilled, density rules require the assignment of a specified number of acres to the well so that the wells in a specific field may be drained efficiently.  Id.  Frequently, when a tract is too small to satisfy state spacing or density requirements, lessees will pool acreage from different leased tracts into a single unit. Id. at 634.  “Operations anywhere within the unit are treated as if they occurred on all the land within the unit, and production from a well on the pooled unit is treated as occurring on all the tracts pooled into the unit.”  Id.

With respect to royalty interest owners, “pooling results in ‘a cross-conveyance of interests in land by agreement among the participating parties, each of whom obtains an undivided joint ownership in the royalty earned from the land in the “block” created by the agreement’” and each of whom receives royalty on the basis of the percentage of that party’s acreage to the whole block.  Id. (quoting MCZ, Inc. v. Triolo, 708 S.W.2d 49, 52–53 (Tex. App.—Houston [1st Dist.] 1986, writ ref’d n.r.e.)).  In other words, pooling effects a cross-conveyance among the owners of the minerals under the various tracts in the pool so that all cotenants own undivided interests under the unitized tract in the proportion that their contribution bears to the unitized tract.  Montgomery v. Rittersbacher, 424 S.W.2d 210, 213 (Tex. 1968).  Thus, when an oil and gas lease is executed by all of the owners of different mineral interests in two or more tracts, the royalties payable under the lease will be pooled, and all royalty interest owners in the land subject to the lease will share in production, no matter where the well is drilled on the leasehold.  London v. Merriman, 756 S.W.2d 736, 739 (Tex. App.—Corpus Christi 1988, writ denied). 

An oil and gas lessee has no power to pool, however, without the lessor’s express authorization, usually contained in the lease’s pooling clause.  Tittizer, 171 S.W.3d at 860; Se. Pipe Line Co. v. Tichacek, 997 S.W.2d 166, 170 (Tex. 1999); Luecke, 38 S.W.3d at 634 (holding that lessee’s authority to pool is derived solely from terms of lease, and lessee has no power to pool absent express authority).  “For pooling to be valid, it must be done in accordance with the terms of the methods and purposes specified in the lease.”  Tittizer, 171 S.W.3d at 860; Tichacek, 997 S.W.2d at 170.  Good-faith pooling can be exercised multiple times.  See Expando Prod. Co. v. Marshall, 407 S.W.2d 254, 259–60 (Tex. Civ. App.—Fort Worth 1966, writ ref’d n.r.e.).  However, “[t]he lessors’ land may be pooled only to the extent stipulated in the lease.” Tittizer, 171 S.W.3d at 860 (quoting Jones v. Killingsworth, 403 S.W.2d 325, 327–28 (Tex. 1965)).

Joinder by all interest owners is not necessary for a pooled unit to be valid.  See Ladd Petroleum Corp. v. Eagle Oil & Gas Co., 695 S.W.2d 99, 106 (Tex. App.—Fort Worth 1985, writ ref’d n.r.e.); see also Whelan v. Placid Oil Co., 274 S.W.2d 125, 128 (Tex. Civ. App.—Texarkana 1954, writ ref’d n.r.e.) (holding that tenant in common has right to execute lease on his undivided interest in common property, notwithstanding nonjoinder of cotenant); Donnan v. Atl. Richfield, 732 S.W.2d 715, 717 (Tex. App.—Corpus Christi 1987, no writ) (stating that cotenant has right to incorporate pooling agreement into oil or gas lease without consent or joinder of cotenants, thereby binding his undivided interest). Rather, a tenant in common has the legal right to incorporate a pooling agreement into an original oil and gas lease without the consent or joinder of the other cotenants, creating a valid contract binding the undivided interest of the cotenant making the agreement.  Whelan, 274 S.W.2d at 128.  In such a case, the timely completion of a producing well under the terms of the pooling agreement and within the unit area set out in the unitization agreement will serve to continue the lease in full force and effect so long as gas is being produced in commercial quantities.  Id.  A cotenant who enters into such a lease binding its royalty interest in the completed and producing well and who accepts its pro rata share in the royalties from the well calculated under the terms of the unitization agreement is estopped to deny the validity of the unitization agreement as to its interest therein.  Id. at 129.

A lessee cannot unilaterally terminate a unit that has a producing pooled well.  See Ladd Petroleum Corp., 695 S.W.2d at 106–07.  Rather, for a lessee to terminate a unit, either the lessors must agree to the unpooling or the lease must expressly authorize such termination. Id. at 107.  When a lease provides that a lessee may dissolve a unit, once formed, if there is no “unitized substance” being produced from the unit, the lessee may not dissolve a unit as long as a well is still producing on it.  See Williamson v. Mobil Producing Tex. & N.M., Inc., 737 S.W.2d 917, 921 (Tex. App.—Beaumont 1987, writ denied) (“So, clearly, the lessee, if it is ‘after the discovery of the same,’ can change the pooling unit only subsequent to the cessation of production. . . .”).

However, when a mineral interest owner accepts royalty checks from a pooled unit, he has accepted that unit.  See Montgomery, 424 S.W.2d at 214–15; Cambridge Prod. Inc. v. Geodyne Nominee Corp., 292 S.W.3d 725, 732 (Tex. App.—Amarillo 2009, pet. denied).  Moreover, under the doctrine of equitable estoppel, a person or party may not maintain a position inconsistent with one in which it acquiesced or from which it accepted a benefit.  Cole v. Anadarko Petroleum Corp., 331 S.W.3d 30, 40 (Tex. App.—Eastland 2010, pet. denied).  Similarly, under the doctrine of quasi-estoppel, one may not accept the benefits of a transaction and then adopt an inconsistent position to avoid corresponding effects, e.g., accepting the benefits of an agreement and then arguing that the agreement is invalid.  Id. at 41–42 (holding royalty owners were not equitably estopped to declare 1925 lease under which they had received royalty payments terminated, although they continued to receive royalties under lease, when there was no evidence that after declaring termination of lease they accepted lease payment or any other benefit that accrued only because of continued viability of lease); cf. Cambridge Prod., 292 S.W.3d at 732 (holding that, under doctrine of equitable estoppel, mineral interest owners could not repudiate unit designation after accepting royalties attributable to unit).  Therefore, a previously designated unit necessarily terminates upon the agreement of all the lessors to participate in a new unit that is incompatible with the prior unit; and the parties who have consented to a new unitization of the same interests are estopped to deny the termination of the prior inconsistent unit designation.

Here, Samson argues that because the DuJay 1 unit’s acreage conflicted with the earlier BSM A-1 unit the later DuJay 1 unit could not have been formed and approved by regulatory authorities or accepted by the Hooks if the BSM A-1 lease had still been in effect.  It contends that when the Hooks accepted royalty checks measured according to their participation in the “amended unit,” the DuJay 1 unit, they were consenting to their participation in the DuJay 1 unit.  Thus, the Hooks understood and acknowledged by their acceptance of royalties from production from the DuJay 1 unit that the BSM A-1 unit was not formed. Samson further contends that, under the terms of the Hardin County Leases (as well as under regulatory restrictions), the Hooks could not pool the same acreage twice to the same depths.

The Hardin County Leases granted Samson the authority to pool those leases with other land or leases. Under that authority, Samson obtained the Hooks’ agreement to pool their interests with the undivided interests of the two drillsite lessors, Black Stone Minerals and FirnBank, in the BSM A-1 unit.  One of the two drillsite lessors—FirnBank—consented to the BSM A-1 unit.  In addition, Samson pooled other lands and its own working interests into that unit. However, Black Stone Minerals refused to pool.  Samson had no authority to pool Black Stone Minerals’ interests without its express consent.  See Tittizer, 171 S.W.3d at 860; Tichacek, 997 S.W.2d at 170; Luecke, 38 S.W.3d at 634.  But it did not lack authority to form a gas production unit that included the mineral interests of Black Stone Minerals’s cotenant, FirnBank.  See Ladd Petroleum Corp., 695 S.W.2d at 106; Whelan, 274 S.W.2d at 128.

The Hooks argue that, under Whelan and Ladd Petroleum, the BSM A-1 unit was validly formed when FirnBank, the owner of a 12.5% undivided interest in the mineral rights to the drillsite, consented to the unit and that this pooled unit could not be vacated or amended so long as gas continued to be produced from the BSM A-1 well. The Hooks agreed to the pooling of their Hardin County Leases in the BSM A-1 unit.  Therefore, they argue, they are entitled to royalties from the BSM A-1 well.

We agree with the Hooks that the originally designated BSM A-1 unit was validly formed, creating a valid contract binding FirnBank, the cotenant making the agreement, and the Hooks. See Whelan, 274 S.W.2d at 128.  However, FirnBank pooled only its own undivided 12.5% interest in the production from the unit. See id. at 129.  The unit that was created for the BSM A-1 well did not include the interest of Black Stone Minerals, who had not consented to pool its undivided mineral interest in the drillsite lease, as a lessor.  See Tittizer, 171 S.W.3d at 860; Tichacek, 997 S.W.2d at 170; Luecke, 38 S.W.3d at 634.  Moreover, neither FirnBank nor the Hooks had the authority to bind Black Stone Minerals to their own agreement to pool.  See Montgomery, 424 S.W.2d at 213; Whelan, 274 S.W.2d at 128.

Recognizing these facts, Samson treated Black Stone Minerals’ lease as continuing as an independent lease that was not pooled in any unit, even though the Hardin County Leases and FirnBank’s undivided 12.5% interest in the acreage of the designated unit, as well as the leases of the other consenting landowners, did constitute a valid unit.  The completion of a producing well, the BSM A-1, within the unit area set out in the unitization agreement served to continue the leases granted to Samson by FirnBank, the Hooks, and the other landowners in full force and effect so long as any “unitized substance” continued to be produced from the BSM A-1 well, subject to unpooling through agreement of the lessors, or through cessation of the production of unitized substance as provided in the habendum clause of the Hardin County Leases.  See Ladd Petroleum Corp., 695 S.W.2d at 107; Whelan, 274 S.W.2d at 128.

When Black Stone Minerals refused to pool, however, Samson was forced to look for other strata and acreage with which to pool in order to unitize the field for production consistent with spacing and density regulations.  It designated an “amended” unit that included reduced acreage from the Black Stone Minerals/FirnBank lease as well as the Hardin County Leases and others from the original BSM A-1 unit, including the State’s leases.  The new unit did not include the horizon from which the BSM A-1 well was producing, but it did include deeper strata that had been included in the BSM A-1 unit, including the depths from which the DuJay 1 well was producing.  Samson named this redesignated unit the DuJay 1 unit, and it subsequently designated a second new gas production unit that conflicted with the original BSM A-1 unit, which it named the DuJay A-1 unit.  The DuJay A-1 unit included different strata not included in the DuJay 1 unit.  Samson pooled the Hooks’ interests and those of the other interest holders in the designated BSM A-1 unit into the DuJay 1 unit and the DuJay A-1 unit, pursuant to its right under the Hardin County Leases to exercise pooling authority multiple times, “at any time and from time to time . . . .”

Because the DuJay 1 and DuJay A-1 units conflicted with the designated BSM A-1 unit, which had a producing well on it, that previous unit could be terminated only by the agreement of the lessors—who had bound themselves to their agreement to pool their leases in the BSM A-1 unit—to amend that unit and to accept the subsequently designated conflicting units. See Cambridge Prod., 292 S.W.3d at 732; Ladd Petroleum Corp., 695 S.W.2d at 107. The Hooks expressly agreed to accept the terms of the new units, binding themselves to accept royalties pursuant to their pro rata share of the royalties from the DuJay 1 and DuJay A-1 units as calculated under the terms of the DuJay 1 and DuJay A-1 unitization agreements, and they did accept royalties from the production of both DuJay units. Those units conflicted with the designation of the same strata in the earlier designated BSM A-1 unit.  By accepting royalty checks from the newly designated, conflicting pooled units, the Hooks accepted those units.  See Montgomery, 424 S.W.2d at 214–15; Cambridge Prod., 292 S.W.3d at 732.  Their interest in the BSM A-1 unit was, therefore, terminated, and they are estopped to deny the validity of the unitization agreements for the DuJay 1 and DuJay A-1 units as to their interest therein.  See Cambridge Prod., 292 S.W.3d at 732; Ladd Petroluem Corp., 695 S.W.2d at 107; Whelan, 274 S.W.2d at 129.

This conclusion is consistent with the language of the Hardin County Leases’ pooling clause itself, which states that “[t]he above right and power to pool may be exercised at any time and from time to time and before or after a well has been drilled, or while a well is being drilled.”  It is also consistent with both Whelan and Ladd Petroleum, relied upon by the Hooks. 

In Whelan, as here, the owner of an undivided interest in minerals refused to execute a pooling amendment and a unit declaration that included his tract in a 696.82-acre pooled unit.  See 274 S.W.2d at 128.  However, his cotenants executed both documents.  See id. at 127.  The court held that the co-owner’s lack of consent did not affect the validity of the unit as between the consenting parties because “[t]he parties to the . . . unit had the legal right to establish the original unit as containing 696.82 acres.”  Id. at 130. 

In Ladd Petroleum, the pooling clause authorized pooling the Blair Lessors’ interests with “other lands, lease or leases.” 695 S.W.2d at 106.  Two leases, the Fulks lease and the Blair lease, were written covering the Blair tract and the adjoining Woody tract.  Id. at 101.  In 1958, the then-lessee of the Fulks and Blair leases and the lessee of a lease covering the Woody tract entered into a pooling agreement for the production of gas and gas condensate.  Id.  Ladd subsequently succeeded to the leasehold interests of the Fulks and Blair leases on the Blair tract and the Woody leases on the Woody tract.  Id.  When the primary terms of the Fulks and Blair leases expired, there was no production from any well on the Blair tract, but there was production from a unit well located on the Woody tract from which the Blair lessors received their pro rata share of royalties.  Id.  In 1976, Ladd inadvertently released all right, title and interest in its oil and gas leasehold interests on the Woody tract.  Id. When it discovered its error, it finalized a new lease with the owner of the Woody tract.  Id. at 102.  When the Blair lessors discovered the release, they treated the unit as terminated and demanded that Ladd release its leases on the Blair tract.  Id.  Ladd refused on the grounds that the unit was not terminated by the release and renewal of the Woody lease, that there was still production from the unit, and that development drilling was currently occurring on the unit.  Id.

The Fort Worth Court of Appeals held that, while Ladd’s release of its leasehold interest in the Woody tract terminated one of the two constituent leasehold interests in the 1958 pooling unit, it did not terminate the unit.  The court interpreted the leases, which authorized the lessee to pool the lessors’ leasehold interest, but did not expressly authorize the lessee to terminate a pooling agreement, as not vesting the power to unpool in the lessee.  Id. at 106–07.  It held, “Therefore, an unpooling could only come about through an agreement of the lessors, or through a cessation of production as provided for in the habendum clauses.”  Id. at 107.

Here, there was an agreement by the unitized lessors who had accepted the BSM A-1 unit to accept the inconsistent DuJay 1 and DuJay A-1 units, thereby terminating the BSM A-1 unit.  We hold that the Hooks are estopped by their ratification of the DuJay 1 and DuJay A-1 units to assert an interest in royalties from production from strata not included in those units, including production from the BSM A-1 well. See Cambridge Prods., 292 S.W.3d at 732. This holding is consistent with the purpose of the pooling clauses in the Hardin County Leases, which is to assure the Hooks’ right to a proportionate share in the production of gas subject to drainage from beneath the surface of their land, consistent with the similar rights of others as defined by the regulatory provisions of the Railroad Commission. 

We sustain Samson’s sixth issue.

(b) The Hooks’ Summary Judgment on the “Most Favored Nations” Clause in the Jefferson and Hardin County Leases

In its seventh issue, Samson claims that the trial court erred in rendering summary judgment in the Hooks’ favor on the “most favored nations” lease clause contained in all three of the Hooks’ Leases.  This clause provided that, under certain circumstances, the royalties payable to the Hooks must be elevated to match the highest royalty payable to Samson’s other lessors.  Specifically, the clause provides:

XXIX.         MOST FAVORED NATIONS CLAUSE

          If Lessee shall enter into an oil and gas lease(s) part of which is located within three (3) miles of any exterior boundary of the subject lands covered by the Subject Lease, hereinafter referred to as “Third Party Lease,” Lessee shall notify Lessor of such fact.  If the reserved royalty or the amount per acre payable for delay rentals, shut-in rentals or minimum royalty, at any time payable under such Third Party Lease, is higher than the like royalty and amounts payable as provided in the Subject Lease, the royalty or amount payable per acre in the Subject Lease, which is less than that provided in the Third Party Lease shall be immediately increased so that it will equal the royalty or other amounts payable under the Third Party Lease.  The subject Lease and the Third Party Lease must be calculated in substantially the same manner, such that the comparison of the Subject Lease and the Third Party Lease is based on the same effective net royalty or other payments, and that same shall include or deduct the same types of charges, taxes and other burdens from such interests.

The trial court granted summary judgment in the Hooks’ favor, holding that this clause was triggered by royalty paid to the State of Texas under a pooling agreement with Samson that was higher than the royalty due to the Hooks. 

          It is undisputed that the State of Texas’s lease under Pine Island Bayou (“State of Texas Lease”) is a “Third Party Lease” within the meaning of that term in the most favored nations clause in the Leases in that it covers land located within three miles of the lands covered by the Hooks’ Leases.  The State, like FirnBank and the Hooks, originally consented to pooling to form the BSM A-1 unit.  For that reason, it declined to consent to the subsequent inconsistent DuJay 1 unit. In order to obtain the State’s consent to pool its lease under Pine Island Bayou into the DuJay 1 unit, Samson entered into a pooling agreement wherein Samson became obligated to pay the State a 28.28896% royalty on production, as opposed to the 25% it had been paying the State and was paying to the Hooks.  The issue, therefore, is whether the pooling agreement executed by Samson and the State constitutes a “Third Party Lease,” i.e., an oil and gas lease located within three miles of any exterior boundary of any of the Hooks’ Leases with a higher royalty than that provided for in the Hooks’ Leases, so that Samson’s obligation to pay the Hooks increased royalties under the most favored nations clause in those leases was triggered.

          A most favored nations clause is “a vendor protection clause [that] enables the vendor to receive the benefit of increases in the market price of his product over the term of a long range contract with a purchaser.”  Lone Star Gas Co. v. Howard Corp., 556 S.W.2d 372, 374 (Tex. Civ. App.—Texarkana 1977, writ ref’d n.r.e.).  Such a clause is enforced according to its terms.  See id. at 375–76. 

          The most favored nations clause in the Leases referred specifically to Samson’s obligation to pay the Hooks royalty per acre equal to that payable under any Third Party “oil and gas lease(s) part of which is located within three (3) miles of any exterior boundary of the subject lands covered by [the Hooks’] Lease that Samson entered.”  (Emphasis added.)  Here, however, Samson did not enter an “oil and gas lease” with the State that required it to pay higher royalties per acre than it was paying the Hooks under their Leases.  It entered a settlement agreement, called a “Pooling Agreement,” that raised only the royalty payable to the State on production from the DuJay 1 unit. 

          The difference between the royalties payable to the State on production from the DuJay 1 unit and the royalties paid to the Hooks did not represent a difference in the market price of gas at the time the pooling agreement was entered; nor did it represent a general increase in the royalty rate on the State’s leases.  It was an amount agreed upon by Samson and the State to induce it to accept the amended unit in place of the BSM A-1 unit and to compensate the State for its loss of royalties from the BSM A-1 well due to Samson’s designation of the DuJay 1 unit in conflict with the BSM A-1 unit.  The Hooks recognized that the higher royalties paid to the State under the settlement agreement were not due to a change in the value of gas production from the BSM A-1 well or a generally higher royalty rate for the State that disadvantaged the Hooks, as evidenced by the fact that, after the Hooks both accepted royalties from the DuJay 1 and the DuJay A-1 units and were awarded a higher royalty rate and other damages under the most favored nations clause,[8] they continued to seek additional damages in the form of royalties from the BSM A-1 well.   

          We conclude that, under its plain terms, the most favored nations clause in the Hooks’ Leases does not apply to trigger royalties payable to the Hooks equal to those payable under the settlement agreement reached between Samson and the State.  Therefore, we hold that the trial court erred in granting the Hooks’ motion for summary judgment for damages under the most favored nations clause in the Hardin County Leases.

We sustain Samson’s seventh issue.

3. The Hooks’ Claims Under the Formation Production Clause in the Jefferson and Hardin County Leases

In its fifth issue, Samson complains about the jury’s finding in response to Question Number 8 that Samson’s failure to pay royalty based on formation production resulted in underpayment of royalty under the Hooks’ Jefferson and Hardin County Leases.  Samson contends the issue was erroneously submitted to the jury because the construction of the contractual provision involved was a question of law for the trial court; therefore, the jury’s response to Question Number 8 is immaterial. The Hooks claimed that Samson improperly failed to pay on formation production under their leases.  The trial court submitted this question to the jury. Samson argues that, as a matter of law, the lease provision in question does not require Samson to pay for formation production, as this would require it to pay twice for molecules of gas produced at the surface of the well as liquid condensate.  It also contends that there is legally and factually insufficient evidence that the Hooks’ Leases required Samson to pay to pay twice for those molecules of gas.  It states that by giving effect to the jury’s answer to Question Number 8 the trial court increased all the other categories of damages assessed against it.

Condensate consists of “hydrocarbons that exist in the form of gas when contained in the natural gas reservoir underground, which condense into liquid form when released from the reservoir’s higher pressure and temperature.”  Bowden v. Phillips Petroleum Co., 247 S.W.3d 690, 704 n.7 (Tex. 2008).  When gas is produced, it goes through a mechanical separator through which condensate drops out as a liquid at the wellhead.  The Railroad Commission has implemented a system by which producers report the amount of gas in the reservoir before it is produced.  This system requires producers to use a formula to calculate the volume of reservoir gas produced at the surface as a liquid. “Formation production” is thus the calculation of the total amount of natural gas taken from the reservoir in whatever form it arrived at the surface, whether in the form of gas or in the form of liquid condensate.  Formation production calculations allow the Railroad Commission to track the amount of gas coming out of the ground to avoid overproduction.

Article III of each of the Hooks’ Leases contains several paragraphs specifying how royalties were to be paid.  It reads in pertinent part:

III      ROYALTIES:

Lessors reserve for themselves . . . the following royalties . . .

. . . .

B. (1) On gas, including casinghead gas or other gaseous substances produced from said land, Twenty-Five percent (25%) of the market value at the wells of such gas, or Twenty-Five percent (25%) of the price received therefor by Lessee, which ever is greater . . .

C.   An equal Twenty-Five percent (25%) part of all other liquid hydrocarbons that may be produced from said land . . .

          . . . .

K. For the purposes of calculating all royalties payable under Article III herein, it is expressly provided that all such calculations shall be based on formation production as reported on Texas Railroad Commission forms P-1 and P-2.

The Hooks base their formation production argument on Article III(K).  They contend that although this provision expressly refers to the entire Article III, which covers payments for both liquids and gas, it requires that all calculations shall be based on gas as it exists in the reservoir so that royalties must be paid on liquid condensate both as it is produced in liquid form and as it exists in gaseous form in the reservoir.

The interpretation of the formation production provision in the Hooks’ Leases is a matter of contract construction.  Whether a contract is ambiguous is a question of law for the court.  J.M. Davidson, Inc. v. Webster, 128 S.W.3d 223, 229 (Tex. 2003).  We construe the parties’ intentions as expressed in the document, considering the entire writing and attempting to harmonize and give effect to all of the contract’s provisions with reference to the whole agreement.  Frost Nat’l Bank v. L & F Distribs., 165 S.W.3d 310, 311–12 (Tex. 2005).  “We construe contracts ‘from a utilitarian standpoint bearing in mind the particular business activity sought to be served’ and ‘will avoid when possible and proper a construction which is unreasonable, inequitable, and oppressive.’” Id.; accord Ace Ins. Co. v. Zurich Am. Ins. Co., 59 S.W.3d 424, 428 (Tex. App.—Houston [1st Dist.] 2001, pet. denied).  If, after the rules of construction are applied, the contract can be given a definite or certain legal meaning, it is unambiguous and we construe it as a matter of law.  Frost Nat’l Bank, 165 S.W.3d at 312.

          Article III of the Hooks’ Leases, governing the payment of royalties, addresses a number of royalty payment issues.  In each case, it unambiguously states that Samson will pay 25% of the proceeds it receives, whether for gas or for liquids, as royalties to the Hooks unless the proceeds are below market value, in which case it must pay 25% of market value.  In no place do the Leases state that, having paid royalties to the Hooks from the proceeds it receives on the sale of gas or liquid condensate, Samson must pay for the condensate a second time as it existed as gas in the reservoir.  Article III does not state that Samson must pay a 25% royalty on “formation production” in addition to royalty on gas and liquids as produced, and we decline to read that provision into the unambiguous language of the Lease.  See Mann Frankfort Stein & Lipp Advisors Inc. v. Fielding, 289 S.W.3d 844, 850 (Tex. 2009) (“[T]erms are to be implied in contract, not because they are reasonable, but because they are necessarily involved in the contractual relationship, such that the parties must have intended them and must have failed to express them only because of sheer inadvertence or because they are too obvious to need expression.”).  We agree with Samson that the unambiguous meaning of these lease provisions is that the Hooks are entitled to a 25% royalty on all gas and liquid hydrocarbons.  

          We hold that, under its plain language, the formation production clause in Article III(K) of the Hooks’ Jefferson County and Hardin County Leases does not operate to double the amount of royalties owed on the liquid condensate produced from the well.   Therefore, the trial court erred in awarding the Hooks damages calculated under the formation production clause in their Leases.

          We sustain Samson’s fifth issue.

4.     The Trial Court’s Grant of a Permanent Injunction

          In its eighth issue, Samson claims that the trial court erred by granting a permanent injunction in its judgment that requires it to fulfill certain contract provisions upon pain of contempt of court. Samson claims that no evidence was presented of the necessary elements for a permanent injunction. 

The first item of injunctive relief requires Samson to pay the Hooks royalty on production from the BSM A-1 well commencing with production after May 2008.  The fourth item states that Samson shall be liable for all ad valorem taxes on the Hooks’ interests in the oil and gas leases at issue after November 2007, as long as those leases are in effect. The fifth item requires Samson to provide the Hooks with certain notices and information “as required by the oil and gas leases in this case while those leases are in effect.”

A permanent injunction is proper only when there is evidence of four elements: (1) a wrongful act; (2) imminent harm; (3) irreparable injury, and (4) no adequate remedy at law.  Jordon v. Landry’s Seafood Rest., Inc., 89 S.W.3d 737, 742 (Tex. App.—Houston [1st Dist.] 2002, pet. denied).  The ruling is reviewed for an abuse of discretion.  Id. Courts do not enforce contractual rights by permanent injunction unless the complaining party can show an inadequate remedy at law and irreparable injury.  Cytogenix, Inc. v. Waldroff, 213 S.W.3d 479, 487 (Tex. App.—Houston [1st Dist.] 2006, pet. denied).  Moreover, in order to grant specific performance of a contract via an injunction, present performance of the contract’s terms must be possible.  Id.  “A court should not decree future contractual performance by requiring a party to perform a continuous series of acts, extending through a long period of time, over which the court exercises its supervision.”  Id.  Unless a “significant public interest” is involved, parties to a contract are “left to their remedies at law.”  Id.

The Hooks have failed to cite to us any evidence showing that they are in danger of imminent harm or irreparable injury from Samson’s failure to pay them royalties on production from the BSM A-1 well or ad valorem taxes, or lease notices and information. Nor have they shown that they have no adequate remedy at law for their grievances.  Moreover, at least three of the items of injunctive relief decree future contractual performance, which is forbidden by Cytogenix.  Id.  Accordingly, we conclude that the trial court abused its discretion by including injunctive relief in its order (1) in the absence of any evidence of the elements of a permanent injunction and (2) when the injunctive relief decrees future contractual performance.

We sustain Samson’s fifth issue.[9]

C. CONCLUSION

We reverse the trial court’s final judgment awarding the Hooks damages on their fraud, fraudulent inducement, statutory fraud, and formation production claims and render judgment that the Hooks take nothing by these claims.  We likewise reverse the trial court’s final judgment as it reaffirms and incorporates its summary judgments on the Hooks’ unpooling and most favored nations claims, and render judgment that the Hooks take nothing by these claims.  Because of our holding on these issues, we vacate the trial court’s award of attorney’s fees and post-judgment interest. Finally, we vacate the permanent injunction entered against Samson by the trial court.

II.   The Hooks’ Cross-Appeal

          Before trial, the Hooks and Samson filed cross-motions for summary judgment on the issue of whether Samson breached the offset obligations in the Hardin County Leases.  The trial court granted Samson’s motion and denied the Hooks’ motion on this issue without stating its reasons. 

          The Hooks filed a cross-appeal claiming, in one issue, that the trial court erred in granting Samson’s motion for summary judgment and denying their own.  The Hooks include in this issue sub-issues regarding the correct interpretation of Samson’s offset obligations under the Jefferson County and Hardin County Leases, an exception in the Leases for pre-existing wells, and the statute of limitations. 

          Samson contends that the Hooks have waived their appeal of the summary judgments by failing to preserve it.  It further argues that the trial court correctly interpreted the Hardin County Leases with respect to the issues raised by the Hooks on cross-appeal and correctly rendered summary judgment holding that the Hooks’ offset claims are contract claims that are barred by limitations.

A. Standard of Review

          To prevail on a summary judgment motion, a movant has the burden of proving that it is entitled to judgment as a matter of law and that there is no genuine issue of material fact.  Tex. R. Civ. P. 166a(c); Cathey v. Booth, 900 S.W.2d 339, 341 (Tex. 1995).  Neither party herein argues that a genuine issue of material fact exists which precludes summary judgment; instead, both claim that, as a matter of law, they are entitled to summary judgment based on the language of the Leases.

B. Statute of Limitations

The Hooks’ claims that Samson breached its offset obligations are breach of contract claims.  The four-year statute of limitations applies to the Hooks’ contract claims.  See Stine v. Stewart, 80 S.W.3d 586, 592 (Tex. 2002); HECI Exploration Co., 982 S.W.2d at 885.  “It is well-settled law that a breach of contract claim accrues when the contract is breached.”  Stine, 80 S.W.3d at 592. 

Here, Samson’s breach of its offset obligations occurred ninety days from the date of first production from the wells in question. For the BSM 1 well, the ninety days ran in January 2001.  For the BSM A-1 well, the ninety days ran in September of 2001.  The Hooks did not file suit until November of 2006, more than five years later.    

We conclude that the Hooks’ cause of action for Samson’s breach of its offset obligations was barred by the four-year statute of limitations.

Because our resolution of this issue is dispositive, we do not reach the other sub-issues raised in the Hooks’ cross-appeal.[10]

We overrule the Hooks’ issue on cross-appeal.

III. CONCLUSION

We reverse the final judgment of the trial court against Samson and hold that the Hooks take nothing by their claims, and we vacate the permanent injunction entered against Samson.

                                                                   Evelyn V. Keyes

                                                                   Justice

Panel consists of Justices Keyes, Sharp, and Massengale.

Justice Sharp, concurring in part and dissenting in part.

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[1]           Originally appealed to the Ninth Court of Appeals, this case was transferred to this Court by the Texas Supreme Court pursuant to its docket equalization efforts.  See Tex. Gov’t Code Ann. § 73.001 (Vernon 2005).

[2]           This issue was added at Samson’s request by order dated June 10, 2010, and both parties were required to and did file supplemental briefs thereon.

[3]           Article VI(A) of the Jefferson County Lease provided, in pertinent part, as follows:

[I]n the event a well producing from a unit not comprised of acreage from the leased premises . . . which has been classified as “gas” . . . is completed on adjacent or nearby lands not more than one thousand three hundred and twenty feet (1,320’) from the leased premises, or draining the leased premises, Lessee covenants and agrees to, within ninety (90) days from the date production is first sold, removed or otherwise marketed from said adjacent or nearby producing well, either (1) commence with due diligence operations for the actual drilling of an offset well on the leased premises to the base of the formation from which the adjacent or nearby producing well is producing, (2) pay Lessors as compensatory royalty, in addition to any royalties currently due, a sum equal to the royalties which would be payable under this lease on the production from said adjacent or nearby producing well had same been producing on the leased premises, or (3) in lieu of drilling such offset well or paying such compensatory royalty, release by recordable instrument the offset acreage, as hereinafter defined.  “Offset Acreage,” as used hereinabove, shall be defined as a unit which would surround such a well if same were completed on the leased premises; provided, however, that if any portion of the offset acreage would be included in a producing unit designated by Lessee hereunder, then if Lessee elects to surrender and release such offset acreage, it may retain and except from such release the producing stratum or strata included in such producing unit, but such offset acreage must conform to the depth, size and shape limitations contained in Paragraph V. herein.  The provisions hereof shall apply regardless of whether lands upon which offset wells may be located are owned by Lessor or any of them or not, and with regard to wells located within the hereinabove prescribed distances from the leased premises, regardless of whether drainage is actually proved to be taking place or not.  Notwithstanding anything herein to the contrary, Lessee shall have no obligations under this Article VI in the event a producing well on nearby or adjacent land is already offset by a well on the leased premises or on acreage pooled therewith producing from the same producing horizon from which production has been secured from any well on nearby or adjacent lands.

[4]           The severed lawsuits are Klorer v. Samson Lone Star, No. B-173,008; Bordages v. Samson Lone Star, No. B-173,008-A; and Hooks v. Samson Lone Star, No. B-173,008-B.  Only Hooks has gone to trial.  Klorer and Bordages remain pending.

[5]           Question Four, the question asking for a finding that the harm to the Hooks resulted from fraud, and Question Five, asking for a finding that Samson had actual awareness of the falsity of the representation, instructed the jury to answer the questions only if it unanimously answered “yes” to Questions One and Two.  Only eleven of the twelve jurors answered “yes” to Questions One and Two; therefore, the jury properly refrained from answering Questions Four and Five.

[6]           Question Seven, seeking a finding that Samson secured execution of a document by deception, instructed the jury to answer the question only if it unanimously answered “yes” to Question Four or Five.  Because the jury did not answer Question Four or Five, it properly refrained from answering Question Seven.

[7]           Although the jury found that the Hooks’ cause of action for fraud accrued on “Hooks’ birthday April 2007,” the record shows that Hooks’ birthday was in November and that it was on his birthday in November 2006 that he attended the seminar for oil and gas attorneys where he first heard about the other mineral-rights owners’ suits against Samson.

[8]           The summary judgment on the Hooks’ most favored nations claim included damages under the Hooks’ formation production claim and a large sum for “late charges.”

[9]           In its eighth issue, Samson complains about the grant of attorney’s fees in the final judgment.  The parties stipulated that the Hooks’ right to collect attorney’s fees was contingent on the Hooks’ prevailing at trial and on appeal.  Additionally, in two sentences in its appellate brief, Samson claimed that “[i]t was error to award postjudgment interest of 18% compounded annually.  Instead, the postjudgment interest should be at the same rate as a proper prejudgment interest rate.”  We asked for and received supplemental briefing from both parties on this issue. The supplemental issue, as phrased by Samson, is as follows: “Should the postjudgment interest rate be 5% as set by Texas Finance Code § 304.003, rather than the rate of 18% as stated in the Final Judgment?”  Because we have reversed the judgment in favor of the Hooks so that they are not prevailing parties, upon which their right to attorney’s fees and post-judgment interest are both contingent, we do not reach these issues.

[10]         Likewise, we do not reach Samson’s claims of waiver.