Articles Posted in Recent Cases

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Wikipedia defines “lawfare” as “using legal systems and institutions to achieve a goal.” Some use the term to refer to the misuse of legal systems against an enemy, “such as by damaging or delegitimizing them, wasting their time and money, or winning a public relations victory.” The Fort Worth Court of Appeals used the term in an opinion that has caused quite a stir in legal circles.

The Fort Worth Court’s opinion, in City of San Francisco, et al. v. Exxon Mobil Corporation, et al., 2020 WL 3969558, describes a long-ongoing dispute between Exxon Mobil and California municipalities over lawsuits filed against Exxon and other oil companies in California related to climate change. The appeal is from a trial court decision in a suit brought by Exxon against these municipalities and others under Rule 202 of the Texas Rules of Civil Procedure. That rule allows a trial court to authorize a deposition either to perpetuate or obtain testimony for use in a potential suit, or to investigate a potential claim or suit. The defendants have pending claims in California state courts claiming that Exxon’s activities affect climate change and that its public announcements about climate change were intended to downplay its effects, and seeking damages for nuisance and other relief. Exxon’s Texas suit claims that the California lawsuits were brought to silence and delegitimize Exxon “as a political actor” and to coerce Exxon and other Texas-based energy companies into adopting “the climate change policies favored by special interests and their allies in municipal government.” In other words, lawfare. Exxon said it wants to investigate potential claims for violations of Exxon’s First Amendment rights, abuse of process and civil conspiracy.

The defendants moved to dismiss Exxon’s Rule 202 petition on the ground that the court had no personal jurisdiction over them. The suit could not proceed unless the defendants had sufficient contact with Texas to allow Texas courts to exercise personal jurisdiction. The trial court held that Exxon had established facts to show such personal jurisdiction. The Court of Appeals reversed, holding no such jurisdiction existed.

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Last week the Texas Supreme Court handed down its opinion in Nettye Engler Energy, LP v. Bluestone Natural Resources II, LLC, No. 20-0639, affirming the lower court’s ruling that Engler’s royalty interest bears its share of gas gathering and processing costs.

Engler owns a royalty interest in a section of land in Tarrant County on which Bluestone owns a lease and operates gas wells. Engler’s royalty interest originated in a deed in which the grantor reserved a one-eighth non-participating royalty interest. The deed provides that the grantor reserves “a free one-eighth (1/8) of production … to be delivered to Grantor’s credit, free of cost in the pipe line, if any, otherwise free of cost at the mouth of the well or mine.”

Bluestone contracted with Crestwood Equity Partners to gather its gas through a gathering system owned by Crestwood and deliver it to various delivery points through a processing plant and into a pipeline owned by Energy Transfer, where the gas is sold. Bluestone deducted the gathering fees charged by Crestwood from Engler’s royalty, and the plant processing fees incurred before the gas was sold.

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The Texas Supreme Court agreed to decide Hlavinka v. HSC Pipeline, about which I have written before. The Court’s summary of the issues:

The primary issues in this case are whether (1) Texas law grants eminent domain authority to a pipeline owner shipping polymer grade propylene; (2) a pipeline shipping a product from the pipeline owner’s sole manager to an unaffiliated customer constitutes a public use; and (3) the landowner may properly testify that the highest-and-best use of the taken land is as a pipeline corridor, and value the land through comparisons to past, private pipeline easement sales.

Both parties have appealed. The Hlavinkas argue that HSC does not have eminent domain authority. HSC says Hlavinka’s testimony on value should not have been admissible.

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I wrote about this case before. Today the Texas Supreme Court agreed to hear the plaintiff’s appeal of a judgment of the El Paso Court of Appeals. The Supreme Court’s summary of issues in the case:

At issue in this case is whether courts are barred from considering deed records in a collateral attack on a default judgment. A second issue is whether a rule that bars such evidence shields a default judgment from an otherwise meritorious due process claim. Other issues raised are whether a property owner’s due process rights were violated in obtaining the default judgment and whether the doctrine of laches or provisions in the Tax Code bar a collateral attack on the judgment.

The default judgment was for foreclosure of a tax lien after service by publication. The case has significant due process issues. In a lengthy concurrence in the El Paso court’s judgment, Justice Alley voiced his dissatisfaction with the extrinsic evidence rule but concurred because the court was bound by the Texas Supreme Court precedent. He noted that Ms. Mitchell’s address was in eight warranty deeds that were recorded before the tax suit was filed and could have been easily found.

 

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Pending before the Texas Supreme Court is the petition for review of Ammonite Oil & Gas Corporation challenging the decision of the San Antonio Court of Appeals in Ammonite Oil and Gas Corp v. Railroad Comm’n of Texas, 2021 WL 4976324 (Oct. 27, 2021). The Court of Appeals upheld the RRC’s decision to deny Ammonite’s sixteen applications to force-pool portions of the Frio River into pooled units created by EOG for its horizontal wells in the Eagleville (Eagle Ford-1) Field in McMullen County. The application presents several interesting issues regarding the scope and interpretation of the MIPA.

The State of Texas owns the land within Texas riverbeds. Ammonite leased the oil and gas in the Frio River from the Texas General Land Office. Ammonite then made an offer to EOG to pool adjacent portions of the riverbed into sixteen existing EOG units along the river. (click on image to enlarge)EOG-AmmoniteAmmonite offered to sign an operating agreement with EOG providing for Ammonite to pay its share of costs related to wells in the pooled unit, based on its share of the acreage in the unit. It also offered a 10% “risk penalty.” Ammonite would agree that EOG could recover 110% of its already-incurred costs for wells on the unit before Ammonite would receive its share of revenues from the wells.

EOG rejected Ammonite’s offers and did not make any counteroffer.

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Two recent decisions from two federal judges in the Southern District of Texas, Houston Division, dismissed suits alleging class actions against Apache and Hilcorp for failure to pay royalties on gas used in gas processing plants. Both construed identical lease provisions.

In Carl v. Hilcorp Energy, No. 4:21-CV-02133, Judge Keith Ellison construed a lease with the following provisions:

The royalties to be paid be Lessee are: … on gas, including casinghead gas or other gaseous substance, produced from said land and sold or used off the premises or in the manufacture of gasoline or other product therefrom, the market value at the well of one-eighth of the gas so sold or used ..

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Landowners are often faced with a conundrum: can they accept a royalty check if they believe it is in the wrong amount?

Ms. Strickhausen owns a half interest in the minerals under a tract of land in La Salle County. Her minerals are subject to a lease owned by BPX (then Petrohawk, subsequently acquired by BPX). Her lease expressly prohibits pooling without her consent. The lease of the other half interest in her tract permits pooling. (Ms. Strickhausen’s lease also prohibits commingling of production: “Commingling of production from the Leased Premises with production from other lands or leases shall be prohibited prrior to such accurate metering, measuring and testing, unless commingling is consented to, in writing, by Lessor and each royalty owner.”) BPX filed a pooled unit designation for the WK Unit 4 No. 1H Well and drilled a horizontal well located partly under Ms. Strickhausen’s tract and partly under other tracts. It then asked Ms. Strickhausen to ratify the pooled unit.

Ms. Strickhausen’s lawyer then engaged in a series of communications with BPX seeking to negotiate terms under which Ms. Strickhausen would agree to ratify the pooled unit. The attorney asked BPX how it would propose to pay Ms. Strickhausen if she refused to ratify the unit. BPX replied that it would pay her “based on the length of productive wellbore on the subject tract over the total length of productive wellbore.” BPX claimed that Ms. Strickhausen would receive a larger royalty interest in the well by ratifying the pooled unit than she would if she were paid on a productive-wellbore basis. BPX concluded by saying that, if Ms. Strickausen did not ratify the unit “the royalties will require being placed in suspense.” Continue reading →

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Today a district court in Travis County held that the Texas Railroad Commission violated the Administrative Procedure Act by informally adopting rules for issuance of allocation and production sharing well permits without following the rule-making procedures of the Act. The Court ruled in an appeal by a mineral owner of the Commission’s order granting a well permit to Magnolia Oil & Gas Operating for a well in Karnes County.

The case is Opiela v. Railroad Commission of Texas, No. D-1-GN-20-000099, in the 53rd District Court of Travis County. Judge Karin Crump’s order can be viewed here. Opiela v. RRC Final Judgment (003) Our firm represents the Opielas in the case.

Magnolia’s well, the Audioslave 1H, was originally permitted by Enervest as an allocation well. The Opielas protested the permit, and while the protest was pending the Commission issued the permit and Enervest drilled the well. Magnolia then took over operation of the well and filed an application for an amended permit for the well as a production-sharing well. That permit was also granted over the Opielas’ protest, and Magnolia fracked and completed the well.

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Two unusual cases have recently been decided by the El Paso Court of Appeals, both arising out of the same underlying facts. Both deal with a tax foreclosure on royalty interests.

In the late 1990s an attorney and two mineral buyers got together and proposed to taxing districts to handle tax foreclosure suits for delinquent taxes on royalty interests. The tax foreclosures named a large set of defendants who were served by posting notice of the suit at the courthouse. Texas law allows notice of suit by posting or publication where the plaintiff has tried diligently to locate the defendant and has been unable to do so. The two mineral buyers, Joe Hughes and Duke Edwards, searched the tax records for owners with delinquent taxes, and the lawyer proposed to represent the taxing districts in foreclosing the tax liens. The lawyer’s fee was paid out of the proceeds from the sheriff sale of the royalty interests foreclosed on. Hughes and Edwards were hired to try to locate the delinquent royalty owners so they could be served with the tax suit. For those they could not locate, they provided testimony in the foreclosure suit that they diligently looked for the missing owners and were unable to find them, so the court would authorize service by posting. Hughes and Edwards received an “abstractor’s fee” for each “unlocatable” owner for whom they searched. At the sheriff sale, Duke and Edwards bid on and purchased some of the royalty interests sold.

In Mitchell v. Map Resources, No. 08-17-00155-CV, the El Paso Court of Appeals addressed an appeal of a suit by the Mitchells seeking to set aside a 1999 judgment for taxes and the sale of their interest in royalties. The case resulted in three opinions: the majority opinion by Justice Gina Palafox, a concurring opinion by Justice Alley, and a dissenting opinion by Justice Rodriguez. The court refused to set aside the sale.

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Last week the Texas Supreme Court issued a per curiam opinion, without oral argument, reversing the judgment of the El Paso Court of Appeals  in Sundown Energy LP v. HJSA No. 3 Limited Partnership, No. 19-10654. The lease at issue covers 30,450 acres in Ward County. The case is another illustration of how parties fail to clearly express their intent in drafting retained acreage clauses.

The lease provides that, after the end of its six-year primary term, the lessee must release acreage not held by production unless the lessee was engaged in a “continuous drilling program:”

The obligation . . . to reassign tracts not held by production shall be delayed for so long as Lessee is engaged in a continuous drilling program on that part of the Leased Premises outside of the Producing Areas. The first such continuous development well shall be spudded-in on or before the sixth anniversary of the Effective Date, with no more than 120 days to elapse between completion or abandonment of operations on one well and commencement of drilling operations on the next ensuing well.

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