You fought hard for your lease. You hired a lawyer, negotiated a competitive royalty fraction, and absolutely insisted on a strict “no deductions” clause. When the ink dried, you felt protected. You owned a cost-free royalty.
Then the wells started producing. The first few checks arrived, and the numbers just didn’t add up. When you did the math, you realized your operator was paying you based on a gas price that was noticeably lower than the actual market rate.
We see this all the time at Double Fraction. A family brings us their paperwork, frustrated and confused. They point to the clause in their lease forbidding the deduction of gathering, compression, and processing costs. They point to their check stub. And they ask us: “Are they stealing from me?”
Most of the time, the operator isn’t breaking the law. They are just using a widely accepted accounting trick—a corporate shell game that legally bypasses your hard-won lease protections. We call it the affiliate trap.
Here is how the game is played, how courts are currently ruling on it, and what it actually takes to protect the value of your minerals.
The Anatomy of the Midstream Shell Game
To understand the trick, you have to understand the life cycle of a molecule of natural gas.
When gas comes out of the ground, it usually isn’t ready for a consumer pipeline. It is often wet, sour, and at the wrong pressure. It has to be pushed through gathering lines, compressed, dehydrated, and processed at a plant to strip out the valuable natural gas liquids (NGLs). Only then is the remaining dry gas sold at the “tailgate” of the processing plant to the broader market.
All of that moving and cleaning costs money. These are :post-production costs. If you have a standard lease, the operator deducts your proportional share of these costs from your royalty check.
But let’s say you negotiated a “no deductions” clause. The operator isn’t allowed to charge you for that midstream work. If they sell the gas at the plant tailgate for $4.00, they have to pay your royalty on the full $4.00.
So, what do they do? They sell the gas before it gets processed.
The operator (let’s call them Big Oil Extraction LLC) pulls the gas out of the ground. Right there at the physical wellhead, they sell the unprocessed gas to a midstream company for $2.00. They pay your royalty on that $2.00 price, and technically, they haven’t deducted a single penny for post-production costs. They just sold it cheap.
The midstream buyer then takes the gas, runs it through their gathering lines and processing plants, and sells the finished product on the open market for the full $4.00.
The catch? The midstream buyer is “Big Oil Midstream LLC”—a wholly owned subsidiary of the exact same parent company.
The parent company just took $2.00 of value that should have been subject to your royalty and shifted it over to their midstream subsidiary, where they get to keep 100% of the profit. By using an affiliate sale at an artificially deflated price, they effectively launder your royalty money into their own corporate profits.
The “Arm’s-Length” Illusion
When we explain this to families, their first reaction is almost always: “How can a judge let them get away with that?”
It happens because courts generally enforce the exact words written in a contract. If your lease says your royalty is based on “market value at the well,” then the operator only owes you the value of the gas exactly where it leaves the ground. We took a deep dive into how three words can erase your cost-free royalty in a previous piece, but the affiliate issue adds an entirely different layer of frustration.
When you sell something to a complete stranger who is negotiating against you for the best price, that is an :arm’s-length transaction. The price you agree on is, by definition, the true market value.
When Big Oil Extraction sells to Big Oil Midstream, it is a non-arm’s-length transaction. They are just moving money from the left pocket to the right pocket. But operators will vigorously argue that the $2.00 price they set internally represents the “true” wellhead value.
The federal government refuses to play this game. If you drill on federal land, the Department of the Interior does not let operators use internal affiliate pricing to calculate royalties. Under 30 CFR 1206.142, the federal rules dictate specific, rigid methodologies for valuing processed gas sold under non-arm’s-length contracts. The feds force the operator to trace the gas all the way to the first actual arm’s-length sale to an unaffiliated third party, and calculate the royalty backward from there using strict guidelines.
Private mineral owners don’t have federal regulations automatically protecting their leases. If you want that protection, you have to write it yourself.
The Texas Supreme Court Weighs In
Every now and then, mineral owners take this fight all the way to the top. One of the most important recent battles over this exact issue happened in 2021 with BlueStone Natural Resources II, LLC v. Randle.
The Randle family and several other lessors signed leases back in 2003 with Quicksilver Resources (BlueStone later acquired the leases). They used a standard printed lease form, but they were smart enough to attach a custom addendum. The addendum explicitly stated that its language superseded any contrary provisions in the printed lease.
The printed form contained the dreaded “market value at the well” language. The custom addendum required the operator to compute royalties on the “gross value received” and explicitly forbade post-production deductions.
When BlueStone took over, they began deducting post-production costs, arguing that “at the well” was the only language providing a specific valuation point. They claimed they were just finding the wellhead value. The royalty checks plummeted, and the lessors sued.
The case went to the highest court in the state. According to the 2021 Supreme Court of Texas opinion, the court ruled in favor of the mineral owners.
The justices recognized that “gross value received” inherently conflicts with “at the mouth of the well.” You can’t have both. As detailed in Gray Reed’s legal analysis of the decision, the court concluded that “gross value received” acts as a :gross proceeds equivalent. The term “received” points to the actual money collected at the point of sale, and “gross” means without deductions. Because the addendum was designed to override the printed form, the gross proceeds language won.
The court also handed the owners a victory on a related affiliate issue. BlueStone had been taking commingled gas and using it to fuel off-lease compressors, claiming they were allowed to do so for free under the lease’s “free use” clause. The court shut that down, ruling that the plain language of the free-use clause did not authorize the royalty-free use of gas off the actual leased premises.
How to Protect Your Minerals
The BlueStone case is a rare piece of good news for mineral owners, but it only worked because those owners had specific, powerful language in their addendum.
If you are negotiating a new lease today, the standard forms handed to you by a landman will not protect you from the affiliate trap. The Texas Real Estate Research Center has excellent guidance on this. As they point out, every single provision in a lease is negotiable, and your protection lives or dies in the addendum.
To stop the shell game, you need an “Affiliate Clause.”
A strong affiliate clause dictates that royalties cannot be based on a sale to a subsidiary, parent company, or any entity sharing common ownership with the lessee. It forces the operator to calculate your royalty based on the gross proceeds received at the first arm’s-length sale to an unaffiliated third party.
If the operator sells the gas to their own midstream company for $2.00, and the midstream company sells it to a power plant for $4.00, an affiliate clause forces the operator to pay your royalty on the $4.00. It pierces the corporate veil.
You also need to be careful about how your check stub reads. If you’re trying to figure out if this is happening to you right now, it takes some detective work. We’ve written about how to read your royalty statement before, but catching affiliate pricing often requires going beyond the stub. You have to look up the corporate registration of the buyer listed on your check and see if they share an address or executives with your operator.
Sometimes, you might just notice your operator’s price per MCF is consistently 30% lower than the Henry Hub benchmark. While there are legitimate reasons for local price differentials—which we covered in why your royalty check just shrank—a massive, persistent gap is a red flag.
The Exhaustion of the Audit Trail
I genuinely don’t know how the average family is expected to manage this long-term.
To ensure you are being paid correctly, you basically need to operate a part-time audit firm. You have to monitor local gas indices. You have to track the corporate subsidiaries of multi-billion dollar energy conglomerates. You have to hire specialized attorneys to draft ironclad addendums, and then you have to hire them again ten years later to enforce those addendums when an operator decides to test their luck.
We have the resources to fight these battles at Double Fraction because we manage large mineral portfolios. We have the data, the software, and the legal frameworks to hold operators accountable. But for a family managing an inheritance, the sheer friction of dealing with oil companies can drain the joy right out of owning the asset.
This is the reality of modern mineral ownership. The days of signing a lease, putting it in a drawer, and trusting the checks are over.
Some families thrive on managing these details. They treat their minerals like an active business, and they do it well. But others reach a point where they realize the ongoing administrative headache, the legal risk, and the constant vigilance just aren’t worth it anymore.
When you know exactly what your minerals are worth in today’s market—fully audited, fully valued—you suddenly have options. You can choose to keep fighting the midstream shell game, or you can trade that future uncertainty for peace of mind today.
If you’re tired of scrutinizing every check stub and wondering if your operator’s midstream affiliate is eating your profits, it might be worth a conversation. At the very least, you deserve to know what your minerals are actually worth so you can make an informed decision for your family.
:post-production-costs
These are the expenses incurred by an operator after oil or gas is brought to the surface. They include the costs of gathering the gas in pipelines, compressing it to move it along, dehydrating it to remove water, treating it to remove impurities, and processing it to extract valuable liquids. Operators generally try to pass a proportional share of these costs onto the royalty owner unless the lease explicitly prohibits it.
:arms-length-transaction
A deal between two independent, unrelated parties who are both acting in their own self-interest to get the best possible price. In oil and gas, an arm’s-length sale of production represents the true fair market value because neither side has an incentive to artificially inflate or deflate the price to benefit a corporate parent.
:gross-proceeds
The total, unreduced amount of money a seller receives from a buyer before any expenses, taxes, or costs are subtracted. In mineral leasing, securing a “gross proceeds” valuation for your royalty is a major victory because it theoretically forces the operator to pay you a percentage of the entire check they received, protecting you from hidden deductions.