The Brief

Every month, somewhere in a trust officer’s inbox, a royalty statement arrives. It lists a well name, a production volume, a price, a deduction or two, and a final dollar amount. The trust officer logs the payment, files the statement, and moves on. The box is checked. The record is clean.

And somewhere in that statement, there is a very good chance that the number is wrong.

Not fraudulently wrong, necessarily. Not dramatically wrong. Just wrong — in the quiet, compounding way that errors accumulate when no one is looking closely enough. The kind of wrong that doesn’t announce itself. The kind of wrong that looks, at a glance, exactly like right.

This is the case we keep finding ourselves investigating at Shannon Springs. Not because trust managers are careless. They aren’t. But because “reconciliation” as it is typically practiced in a trust setting and “forensic reconciliation” as we practice it are two fundamentally different disciplines — and confusing them has a price.

Exhibit A: What the Typical Trust Reconciliation Actually Does

Let’s be precise about this, because the word “reconciliation” does a lot of heavy lifting in fiduciary circles and deserves scrutiny.

When a trust manager reconciles a royalty payment, the process generally looks like this: the statement arrives, the payment is logged against the prior period’s amount, the revenue is recorded in the trust’s books, and the statement goes into the file. If the payment is roughly consistent with recent history — not wildly lower, not suspiciously absent — the reconciliation is considered complete.

In accounting terms, this is a cash-basis receipt verification. The question being answered is: Did the money arrive?

That is a legitimate question. It is also the least interesting one you can ask about a royalty remittance.

What it does not answer: Was the amount correct?

The trust manager is matching a deposit to a statement. The statement is produced by the operator. The operator calculates the payment using a formula derived from the lease — a lease that may be years old, may have been amended, and was almost certainly written in language that gives the operator considerable latitude on deductions. The trust manager is, in effect, confirming that the operator paid what the operator said it would pay. This is like a restaurant verifying its own bill.

To be fair, this is not negligence. It reflects a structural reality: trust managers are administrators, not petroleum analysts. They oversee many assets. They are not equipped — and are generally not expected — to interrogate the internal arithmetic of a royalty payment. They trust the statement. They file it. They move on.

The problem is that the statement may not deserve that trust.

Exhibit B: Where the Money Goes Missing

Royalty payment errors are not rare. They are, based on what we see at Shannon Springs, a persistent feature of the mineral royalty system rather than an anomaly. They take several forms, and each one is invisible to a standard trust reconciliation.

Improper post-production deductions. The lease governs what an operator may deduct from gross revenues before calculating your royalty — transportation, gathering, compression, processing. Many leases prohibit or limit these deductions. Many operators apply them anyway, or apply them in ways that exceed what the lease permits. The statement won’t tell you this. It will simply show a lower net revenue figure with a line item labeled “deductions.”

Incorrect working interest or net revenue interest allocations. The fraction of production attributable to a particular mineral interest is established in the lease and in title. When wells are re-permitted, when interests change hands, or when operators update their division orders, errors in the ownership decimal creep in. Your trust may be receiving royalties calculated on a slightly smaller interest than the one it actually holds. Each check will look normal. The cumulative underpayment, however, can be substantial.

Pricing variances from market benchmarks. Royalties are typically calculated on the sale price of production. That price should reflect prevailing market conditions at the delivery point. Operators have discretion in how they sell production and how they report the sale price to royalty owners. When reported prices diverge from published index prices for the same commodity at the same location in the same month, there is a question worth asking. Standard trust reconciliation never asks it.

Skipped periods and timing irregularities. Production occurs in one month; payment follows, often with a lag. When operators skip a payment period, the gap may not be immediately obvious — particularly when production is intermittent or when a trust holds interests in many wells. A careful accounting of production periods against payment periods catches these. A standard log-and-file does not.

Royalty-on-royalty netting errors. In older leases, particularly those in Oklahoma and Texas with complex ownership histories, the calculation of net royalty owed can involve stacking multiple fractional interests. These calculations are error-prone. They are rarely verified.

None of these errors surface in a trust manager’s standard process. They exist, if they exist, inside the statement — not missing from it.

Exhibit C: The Forensic Difference

What Shannon Springs does is not a better version of the same reconciliation. It is a different activity entirely, operating at a different layer of the documents.

We begin where the standard reconciliation ends: with the statement in hand. Then we go backward — to the lease, to the division order, to state production records, to published pricing indices, to the regulatory filings the operator submitted to the railroad commission or conservation agency. We reconstruct what the payment should have been, from independent sources, and compare that to what was actually paid.

This is the distinction between confirming a number and verifying a number. One accepts the operator’s arithmetic as the starting point. The other derives an independent answer and tests the operator’s arithmetic against it.

The work is methodical and document-intensive, which is why it is not done routinely. It requires the lease, the title chain, historical production data from state databases, commodity pricing histories, and, ideally, several years of statements. It requires someone who understands both petroleum engineering conventions and accounting principles — not a common combination. And it requires time.

The result, when we complete an engagement, is not simply a list of discrepancies. It is a sealed evidence package: a documented audit trail showing the source of every calculation, every comparison, every finding. The trustee gets a one-page Advisor Review suitable for the trust file and a workpaper package suitable for legal proceedings if one ever becomes necessary.

The trust manager’s reconciliation creates a record that payments were received. The Shannon Springs forensic audit creates a record that payments were correct — or documents precisely where they were not.

The Case for Fiduciaries

There is a question that surfaces in almost every conversation we have with trustees and estate attorneys: Am I required to do this?

The honest answer is that the law is still catching up to the complexity of mineral royalty accounting. Fiduciary duty standards generally require prudent management, not forensic perfection. A trustee who logs statements and files them is not, in most jurisdictions, in obvious breach.

But prudent management standards are not static. They are informed by what a reasonable trustee could have known and should have investigated. And as forensic royalty reconciliation becomes a recognized service — as the existence of firms like Shannon Springs becomes more widely known in fiduciary circles — the question of what a reasonably prudent trustee would do begins to shift. Firms offering true forensic royalty reconciliation — independent source verification, sealed workpapers, lease-level analysis — remain uncommon in the trust services market, which makes engaging one a meaningful distinction in any fiduciary record.

There is also the practical matter of what happens when a beneficiary asks questions. Did you verify that the royalty payments were accurate? If the answer is we confirmed the checks cleared, that is a different conversation than we had an independent forensic audit conducted and here is the sealed workpaper package. One of those answers closes the inquiry. The other opens it.

We are not in the business of creating fiduciary anxiety. But we do think that mineral-owning trusts deserve the same quality of oversight that other trust assets receive. A publicly traded portfolio gets priced daily. A real estate holding gets appraised. A mineral interest that generates monthly remittances from a third-party operator — and that cannot be independently priced without data the operator controls — deserves, at minimum, a periodic forensic check on the arithmetic.

Closing the Case

The checked box is not the enemy. Administrative reconciliation has its place. It is the right tool for confirming that the machinery of payment is functioning — that checks are arriving, deposits are posting, nothing has gone dark.

It is simply not sufficient for the question that matters: Is the trust receiving what it is owed?

That question requires a different kind of investigation. It requires working from independent sources rather than the operator’s statement. It requires someone who knows what to look for in a lease, what deductions are permissible, how production data maps to payment periods, and how pricing is supposed to be calculated. It requires documentation that would survive scrutiny.

Standard reconciliation closes the file. Forensic reconciliation opens the lease.

The difference, in our experience, is often a meaningful sum of money.

Case filed.