By Brad Caponigro · Founder, Pointer Petroleum LLC · Reservoir engineer
Published
Imagine a mineral owner in Martin County, Texas, sitting on 80 unleased acres while three operators run laterals on every quarter section around them. Production reports start showing big numbers from neighboring sections — wells whose toes appear, on the plat, to be aimed straight at the owner's tract. The instinct is to call a lawyer and demand compensation for the gas being pulled out from under the property. The Texas answer, going back to a coal case from the 1840s, is uncomfortable: in this state, the only way to claim hydrocarbons under your tract is to have a wellbore on it. Drainage from the next section over is, by long-settled rule, somebody else's production. Knowing where that rule stops — and where it leaves room for a real claim — is the difference between a meritless lawsuit and a check.
Texas oil and gas law starts from the rule of capture: the owner of a tract is entitled to the oil and gas produced from a well on that tract, even if the production drains hydrocarbons that migrated from a neighboring tract. The doctrine traces to the 1840s English coal cases, was adopted in Texas in Brown v. Humble Oil & Refining Co. (1935, 126 Tex. 296), and has been reaffirmed repeatedly — most recently in the hydraulic fracturing context in Coastal Oil & Gas v. Garza Energy Trust (2008, 268 S.W.3d 1).
The practical consequence: if your neighbor leases to an operator who drills a well 200 feet from your property line and drains a substantial portion of the gas from under your tract, you generally have no claim. The hydrocarbons did not "belong" to you in any actionable sense until reduced to possession at a wellbore — and reducing them to possession is exactly what the neighboring operator did.
The rule of capture sounds harsh, and it is. It is partially offset by three counter-rules: spacing regulations administered by the Texas Railroad Commission (RRC), the operator's implied duty to protect a leased tract from drainage, and the very limited statutory protections under the Mineral Interest Pooling Act (MIPA) discussed in our separate post on Texas forced pooling. None of these counter-rules eliminates the basic rule. They modify how it operates in specific situations.
The most important takeaway for mineral owners is structural: in Texas, the only reliable way to capture the value of hydrocarbons under your tract is to lease the tract to an operator who will drill it (or drill a well that drains the area into your tract). Sitting on unleased minerals while neighbors develop is usually an economic loss, not a position of strength.
When a Texas operator already holds a tract under lease, the rule of capture is modified by the implied covenant to protect against drainage. The leading case is Amoco Production Co. v. Alexander (1981, 622 S.W.2d 563), where the Texas Supreme Court held that an operator who holds adjacent leases — and produces from one in a way that drains the other — owes the lessor of the drained tract a duty to either drill an offset well or otherwise protect the lease.
The duty has four practical elements as developed by Alexander and its progeny:
Drainage in fact. The lessor must prove that production from the neighboring tract is actually drawing hydrocarbons from under the leased tract. This is typically a reservoir-engineering question — pressure transient analysis, declining bottom-hole pressures, production-history modeling — and requires an expert witness in any contested case.
A reasonable operator would act. The lessor must prove that a reasonable, prudent operator under the same circumstances would have drilled an offset well or taken other protective action. This includes economic analysis: the proposed offset must be expected to produce at a profit at the time it should have been drilled, after considering capital costs, operating costs, expected reserves, and price.
The operator failed to act. Documentation of what the operator did and did not do — drilling permits filed, AFEs circulated, internal economics — is the core evidence.
Damages. Texas measures drainage damages by the royalty the lessor would have received on the offset well had it been timely drilled. This is calculated by simulation of the offset well's expected production stream at the relevant royalty fraction.
The Alexander cause of action survives but is hard to win. Operators have learned to insulate themselves by drilling token offsets, by documenting economic analyses showing the offset was uneconomic, and by including limiting language in modern lease forms (some leases expressly waive or modify the implied covenant). The most successful Alexander cases have involved operators who held both the producing and drained leases and could be shown to have made deliberate choices to favor the producing tract.
For a mineral owner who suspects drainage from a leased neighboring tract, the first practical step is a written demand letter to your operator: identify the producing wells, demand information about offset planning, and request that the operator either drill the offset or release the relevant acreage. Most legitimate Alexander disputes settle at this stage with either a demand-letter offset commitment or a partial lease release.
A more aggressive scenario arises when an operator drills a horizontal well whose lateral crosses your unleased mineral tract without your consent. Texas operators routinely drill these "allocation wells" under Rule 37 spacing exceptions when they cannot or do not want to lease every tract along the proposed lateral path. The RRC permits the well; the operator drills; production is "allocated" between tracts based on lateral footage; and the unleased owner is left to figure out what their rights are.
The operator's position is that the unleased owner is entitled to a proportional share of net production proceeds — essentially, the unleased acreage's share of lateral length times sales revenue, minus that share of completed-for-production cost. There is no bonus, no contractual royalty, and the accounting is whatever the operator says it is.
The unleased owner's position is that the operator drilled across their minerals without authority. Depending on the facts, this can be framed as trespass, conversion, unjust enrichment, or breach of a quasi-contract — and the relief sought can include actual damages, the unleased owner's working-interest share of revenue gross of cost recovery, lease bonus that should have been paid, and in some cases punitive damages.
The Texas case law on allocation wells across unleased tracts is unsettled. Browning Oil Co. v. Luecke (1999, 38 S.W.3d 625) recognized that production from a horizontal pooled unit crossing multiple tracts must be allocated among those tracts. Magnolia Petroleum Co. v. Connellee (1942) and the long line of pre-horizontal trespass cases inform the trespass framing. But no Texas Supreme Court case has squarely answered the central question: when an operator drills across an unleased tract without consent, what does the unleased owner recover? The trial-court and intermediate-appellate decisions are inconsistent.
The RRC does not adjudicate this question. The agency permits the well under spacing rules without ever determining ownership rights between the operator and the unleased mineral owner. That determination — whether the operator owes net proceeds, gross proceeds, lease bonus, or trespass damages — is left to civil court.
The practical consequence is that an unleased owner whose tract has been crossed by an allocation well is in an asymmetrical negotiation. The operator has already drilled, so the operator controls the timing. The owner's leverage is the threat of litigation against an unsettled legal question — which the operator wants to avoid because losing would set bad precedent across its entire allocation-well portfolio. Most of these disputes settle at terms that look like a post-drilling lease: a small bonus and a royalty fraction calculated against gross proceeds, with cost deductions limited or eliminated.
Beyond the allocation-well scenario, several other situations involve drilling without a valid lease — each with different remedies:
Lease has expired. The lease ran past its primary term without sustained production in paying quantities, the operator drilled (or continued producing) anyway, and you contend the lease has terminated. The remedy depends on whether the lease is in fact terminated. If yes, the operator is producing as a trespasser and owes the unleased mineral owner the trespass measure of damages — typically gross proceeds without deduction for cost (the "good faith trespasser" doctrine softens this in some cases by permitting cost recovery if the operator believed in good faith that the lease was valid; see Houston Production Co. v. Mecom Oil Co., 1933, 62 S.W.2d 75). If the lease is still valid (production in paying quantities is genuinely contested), the case is a habendum-clause dispute rather than a trespass case. See our separate post on producing in paying quantities for the Texas standard.
Unknown mineral owner / heir. The operator drilled under a lease from one of several record co-tenants, but did not lease the others. The unleased co-tenants are entitled to their share of net production proceeds (the operator has the right to produce as a co-tenant, and the unleased co-tenants get net rather than gross — Cox v. Davison, 1965, 397 S.W.2d 200). The accounting and the burden-of-proof on costs are the contested elements. Often these cases resolve as a quiet-title and accounting action together.
Fraudulent or void lease. The lease was procured by fraud, was signed by someone without authority (e.g., one spouse purporting to lease community-property minerals without the other's joinder), or is otherwise void. If void, the operator is producing without authority and the unleased owner has the unleased-owner remedies above. If voidable, the analysis depends on whether and when the owner ratifies or rescinds.
Subsurface trespass via fracturing. Coastal Oil & Gas v. Garza Energy Trust (2008) held that the rule of capture applies to hydraulic fracturing — even if frac fluids and proppant migrate across a property line and cause hydrocarbons under the neighboring tract to flow to the producing well, there is no actionable trespass. The neighbor's remedy is the rule-of-capture remedy: drill an offset (or accept the drainage). This forecloses what was once a fertile area of litigation.
For any of these scenarios, the first practical step is the same: pull the well's permit, the lease records of record on adjacent tracts, and the operator's production reports filed with the RRC. The pre-litigation record review usually clarifies which scenario you are actually in, which controls which remedy is available.
A practical playbook for a Texas mineral owner who suspects drainage of leased acreage, or production from unleased acreage:
1) Pull the public records. Use the RRC's online database (rrc.texas.gov) to identify nearby permitted wells, completion reports (Form W-2), production reports, and well logs. Cross-reference with county courthouse records for leases of record on the relevant tracts. This usually takes a half-day and clarifies which scenario applies.
2) Get a reservoir-engineering assessment if drainage is the issue. For Alexander-style drainage claims, a real claim turns on real reservoir analysis. Petroleum engineering consultants who do this work routinely (often the same firms that do reserve audits for banks) can produce a defensible drainage analysis for $10,000-$30,000. For interests under a few hundred net mineral acres, this is rarely worth the cost up front; for larger interests or for portfolios across multiple tracts, it can pay back many times over.
3) Send a written demand letter. For drainage of leased acreage: demand offset drilling or partial release. For unleased production: demand accounting, demand a copy of the well permit and production records, and reserve all rights. The letter is a prerequisite to most remedies and creates a written record that establishes when the operator was put on notice.
4) Retain Texas oil and gas counsel. The case law in this area is technical and the cases turn on facts that lay owners typically cannot evaluate. Most experienced Texas oil and gas firms will do an initial case assessment for a fixed fee or contingency, and the strongest claims are routinely worked on contingency.
5) Evaluate a sale. The settlement value of these claims is volatile and slow to realize. A trespass case can take 2-4 years to resolve. An Alexander drainage case typically takes longer. During that period, the operator continues to produce and the asset depletes. For owners who would prefer to convert the situation to cash without years of litigation risk, a sale of the mineral or royalty interest is a real option. Pointer Minerals purchases interests with active drainage or allocation-well disputes — our underwriting accounts for the asymmetry between the operator's position and the owner's, and the offer reflects what the interest is realistically worth on the current production trajectory regardless of the litigation outcome.
The Texas drainage and unleased-production landscape rewards owners who act on facts and pull permits early. It punishes owners who wait — every month of un-asserted drainage is a month of lost production that the rule of capture will not give back.
Generally no. Under the Texas rule of capture (Brown v. Humble Oil, 1935; reaffirmed in Coastal Oil v. Garza, 2008), an operator producing from a well on a neighboring tract is entitled to the production even if it drains hydrocarbons that migrated from under your unleased tract. Your remedy is to lease your tract and have it drilled, or to drill it yourself — not to sue the neighbor. The rule of capture is a structural feature of Texas law, not an exception. Limited exceptions exist for waste violations and for some MIPA scenarios, but they are narrow and rarely available to a mineral owner.
When the operator already holds your tract under lease, Amoco v. Alexander (1981) imposes an implied covenant to protect the lease from substantial drainage by the operator's own production from neighboring tracts. The lessor must prove (a) drainage is happening, (b) a reasonable prudent operator would drill an offset, (c) the operator failed to do so, and (d) damages — typically the royalty the lessor would have received on the offset. The cause of action exists but is hard to win because the offset must be shown to be economically prudent at the time it should have been drilled. Modern operator lease forms also frequently include language modifying or limiting the duty.
The Texas case law is unsettled. The operator's position is that you are entitled to net proceeds (your share of lateral length times revenue, less your share of cost). Your position can be framed as trespass, conversion, unjust enrichment, or breach of a quasi-contract — with potential remedies of gross proceeds, lease bonus, working-interest revenue, and in some cases punitive damages. Most of these disputes settle out of court at terms that look like a post-drilling lease (small bonus plus a royalty fraction with limited deductions). Get oil and gas counsel involved early; pull the well's W-1 permit, completion reports, and production records from the RRC; and consider whether selling the interest is a cleaner path than years of litigation.
Potentially yes. If the lease has terminated for failure to produce in paying quantities (the Texas standard from Clifton v. Koontz and progeny), continued production is unauthorized and the operator is a trespasser. The traditional measure of damages is gross production proceeds without cost deduction, though the "good faith trespasser" doctrine (Houston Production v. Mecom Oil, 1933) sometimes permits cost recovery when the operator genuinely believed the lease was still valid. The threshold question — whether the lease actually terminated — is fact-intensive and turns on production economics during the contested period. Legal counsel and a production-data review are the first steps.
Alexander drainage cases routinely run 3-5 years from filing to resolution, and longer if appealed. Allocation-well and trespass cases often settle within 1-2 years of filing because operators want to avoid setting bad precedent in unsettled areas of law. Settlements typically take the form of a post-drilling lease (back-pay of bonus and royalty plus going-forward royalty at a negotiated rate), a one-time cash payment in exchange for a release, or some combination. The operator's leverage is delay; the owner's leverage is the precedent risk to the operator's portfolio. Owners who do not want multi-year litigation exposure can sell the interest to a buyer that underwrites both the production cash flow and the unresolved legal exposure — that is part of how Pointer Minerals values these situations.
Primary sources used in writing this article. These are not legal or tax advice — they are the public statutes, regulations, and authoritative materials the article draws from. Consult a qualified attorney or CPA before acting on any of them.
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