You open the envelope, and the number is smaller than last month — even though the well is still producing and prices have not collapsed. Since 2018, Valor has recovered more than $27 million for mineral owners in exactly this situation: checks that looked wrong, and were. Post-production deductions are the single most common reason a royalty check underdelivers, and they are also the most misunderstood line item on the statement. This post covers what those deductions are, why they hit hardest in low-price months, how your lease decides whether they are allowed, and what to do before you call the operator.
What Post-Production Deductions Actually Are
Post-production costs are the expenses an operator incurs to move raw hydrocarbons from the wellhead to a marketable point of sale. The five categories you will see most often on a check stub are:
- 1. Gathering — moving gas through low-pressure pipe from the wellhead to a central point
- 2. Compression — boosting pressure so gas can enter a larger pipeline
- 3. Treating and dehydration — removing water, CO2, and H2S
- 4. Processing — stripping out natural gas liquids like ethane, propane, and butane at a plant
- 5. Transportation — long-haul pipeline tariffs to the sales point
Each of these has a real cost, and someone has to pay it. The question your lease answers — or fails to answer clearly — is whether the operator pays the full cost out of its working interest, or whether it can charge a proportionate share back against your royalty. When deductions are permitted, they scale with your royalty fraction, so every dollar of gathering, compression, and processing booked against the well flows through in proportion to your interest.
The result: two royalty owners on adjacent tracts, producing from the same formation, at the same wellhead price, can receive materially different net checks depending on how their leases were negotiated 10, 30, or 60 years ago.
Why the Math Gets Ugly When Prices Drop
Most gathering, compression, and processing fees are structured as a flat rate per unit of volume — a fixed number of cents or dollars per Mcf. Those fees do not scale with the commodity price. They are the same when gas is trading high as when it is trading low.
The consequence is that the deduction stack takes up a much larger share of gross value in weak-price months. When the sales price falls, the flat fees do not. What used to be a tolerable percentage of the gross becomes a much larger percentage of a much smaller number, and the net royalty compresses hard. That is why owners in dry-gas plays across the country routinely report that a check looks fine one quarter and shockingly thin the next, even when volumes are steady.
Liquids-rich gas is a partial hedge — NGL revenue can offset processing fees — but only if the operator is remitting your proportionate share of NGL proceeds correctly, and only if the plant economics work in your favor that month. Frequently one or both of those conditions is not met, and the owner has no way to see it without reconciling the statement line by line.
“At the Wellhead” vs. “Gross Proceeds” — The Language That Decides Everything
Nearly every dispute over post-production deductions turns on a single clause in the oil and gas lease: where royalty is calculated and what value it is calculated against.
Leases that say royalty is paid on the value at the wellhead generally permit the operator to deduct post-production costs before calculating your share. The logic: if royalty is owed at the wellhead, then any cost incurred downstream of the wellhead to enhance value can be netted back out. Texas courts have generally supported this reading, and the state’s default rule — absent explicit lease language to the contrary — is that post-production costs are shared.
Leases that say royalty is paid on gross proceeds, the amount realized, or the market value at the point of sale — with no wellhead qualifier and often with an express prohibition on deductions — generally do not permit the operator to charge post-production costs back to the royalty owner. Oklahoma has historically been friendlier to the gross-proceeds interpretation than Texas, but the specific language of your lease still controls, and case law continues to evolve in both states.
The practical takeaway: pull your lease, find the royalty clause, and read the exact words. If it says “at the well” or “at the wellhead,” deductions are likely permitted. If it says “gross proceeds received by lessee” or contains an express no-deductions clause, deductions on your check may be improper. This is the single most valuable 15 minutes a mineral owner can spend. For a full breakdown of how to negotiate cost-free royalty language before you sign, read How to Negotiate an Oil and Gas Lease.
How to Actually Read the Statement
Operator check stubs are not standardized. One operator will list deductions as GATH, COMP, TRANS, PROC, DEHY. Another will bundle everything into a single “Deducts” column with no breakdown. A third will show a gross value and a net value with the delta unlabeled. All three are common, and all three are generally legal under state royalty statutes as long as the owner can request detail. If you have never read a check stub line by line, our royalty check stub guide walks through every field.
Here is what to reconcile every month, or at minimum every quarter:
Volumes. Compare the Mcf and BBL on your check to the state regulator’s production reporting — Texas Railroad Commission or Oklahoma Corporation Commission filings. They should match, allowing for a reporting lag.
Price. Compare the price per unit on your check to the posted price or index for that basin and month. A significant discount often signals either legitimate quality and location differentials or an issue worth questioning.
Decimal interest. Confirm the decimal on your check matches the decimal on your division order. Ownership changes, unit revisions, and pooling amendments all shift decimals, and errors are common. If you have not received a division order and believe you should have, here is what to do.
Deduction codes. Ask the operator in writing for a description of every code. You are entitled to know what you are being charged for.
Severance and ad valorem tax. These are separate from post-production deductions. Confirm they match state rates.
If the operator refuses to provide a code key or a breakdown, most state statutes give royalty owners the right to request detailed accounting. In Texas, that request should be in writing and reference the statutory right to information. Persistent refusal is itself a red flag.
When to Push Back — and How
Not every small check is a bad check. Sometimes prices are simply low, a well is in natural decline, or an operator has legitimately incurred higher processing costs because of a plant outage. Pushing back on every downtick will burn goodwill without recovering a dollar.
Push back when the evidence supports it:
- Your lease contains a gross-proceeds or no-deductions clause and deductions are appearing on the check
- Your decimal interest is wrong
- Volumes on the check do not match state filings
- The operator has changed its deduction methodology mid-lease without notice
- You are seeing charges — marketing fees, affiliate transportation fees, unspecified “other” — that do not fit a recognized category
The right sequence is almost always: request a written breakdown of all deduction codes and calculations, compare against your lease language and state production filings, send a formal demand letter identifying the specific charges you dispute and citing the lease clause, and if unresolved escalate to counsel or a professional mineral manager who can pursue audit rights or statutory remedies.
Across the 500,000 wells we cover, the most productive recoveries come from owners who catch the issue early and negotiate from specific evidence rather than general frustration. If your check stopped entirely rather than just running small, read Why Your Royalty Check Suddenly Stopped for the full breakdown on recoupment and shut-ins.
Small royalty checks are sometimes just the market. Sometimes they are a lease-language problem, a decimal error, or an improper deduction that will keep compounding until someone catches it.
Contact Valor Today
If your royalty checks are running smaller than they should and the operator’s math does not add up, a second set of eyes on your statements and lease language is the fastest way to find out why. Contact Valor today for a free, no-obligation review — our royalty management team will audit your check stubs, verify your decimal interest, compare your deductions against your lease language, and flag anything that should not be there. We handle royalty audits and statement reviews for owners across Oklahoma, Texas, and 30 other states.
The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. This blog should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.