How to Read & Audit Your Royalty Statement: A Step-by-Step Guide

#Why Your Royalty Statement Deserves More Than a Glance

If you own mineral rights or hold a working interest in an oil and gas property, your royalty statement is the single most important financial document you receive from your operator. It details how much was produced, what it sold for, what was deducted, and what you are owed. Yet most royalty owners file these statements away without a second look.

That is a costly habit. Industry analysts estimate that between 1% and 3% of royalty payments contain errors, ranging from minor rounding issues to significant miscalculations in decimal interest or unauthorized deductions. Over the life of a producing well — often 20 to 30 years or more — even small monthly discrepancies can compound into tens of thousands of dollars in underpaid revenue.

This guide walks you through every section of a typical royalty statement, highlights the most common errors, and gives you a repeatable audit process to protect your revenue.

#Anatomy of a Royalty Statement

Royalty statements vary in format from operator to operator, but nearly all contain the same core sections. Understanding each one is the foundation of any effective audit.

#Owner Identification

At the top of the statement you will find your identifying information: your name (or entity name), mailing address, and owner number. Some operators also include your tax identification number (SSN or EIN). Verify that this information is correct on every statement. An incorrect tax ID can create problems at year-end when the operator issues your 1099-MISC, and a wrong mailing address can mean missed correspondence about division order changes or lease amendments.

#Property Identification

This section tells you which well or unit the payment relates to. Key fields include:

• Well name — The operator-assigned name for the well (e.g., "Smith Unit #1-H").
• API number — The unique American Petroleum Institute well identifier, typically a 10- or 14-digit number assigned by the state. This is the most reliable way to cross-reference production data with state regulatory filings.
• State and county — The jurisdiction where the well is located, which determines applicable tax rates and regulatory oversight.
• Lease name or unit name — The legal lease or pooling unit under which the well was drilled.

#Production Data

The production section reports gross volumes produced from the well during the statement period, typically a calendar month. Oil is reported in barrels (BBL), and natural gas is reported in MCF (thousand cubic feet) or MMBTU (million British thermal units). Some statements also report NGL (natural gas liquids) volumes separately, measured in gallons or barrels.

Pay close attention to the production month versus the payment month. It is common for royalty payments to lag production by 60 to 90 days, so a check received in April may cover January production. Ensure you are matching the correct production period when comparing against state records.

#Pricing

The pricing section shows the value assigned to each unit of production. This is where confusion — and errors — frequently arise. You may see several pricing terms:

• Posted price — A price published by the purchaser, historically used as a benchmark but increasingly replaced by index-based pricing.
• Actual sale price (or realized price) — The price the operator actually received from the purchaser for that specific sale.
• Gravity adjustment — For crude oil, the price may be adjusted based on API gravity. Oil with a higher API gravity (lighter crude) generally commands a premium, while heavier oil may be discounted relative to the benchmark.
• BTU adjustment — For natural gas, pricing may be adjusted based on the heating value (BTU content) of the gas. A well producing gas with a higher BTU content per cubic foot will receive more per MCF than one producing lean, low-BTU gas.

#Deductions

Deductions are the single most contested area on a royalty statement. Operators may subtract various post-production costs before calculating your net payment. Common deduction line items include:

• Severance (or production) tax — A state-level tax on the extraction of oil and gas. In Texas, the severance tax rate is 4.6% on crude oil and 7.5% on natural gas. Other states have different structures; for example, North Dakota imposes a 5% extraction tax plus a 5% gross production tax on oil.
• Transportation — The cost of moving production from the wellhead or lease facility to a downstream sales point, such as a pipeline hub or refinery.
• Gathering — Fees charged for collecting gas from multiple wells into a central gathering system before it enters a transmission pipeline.
• Compression — The cost of compressing gas to the pressure required for pipeline transport.
• Processing / plant fees — Charges for processing raw natural gas at a gas plant to remove impurities and extract NGLs (ethane, propane, butane, natural gasoline).
• Marketing fees — Fees charged by a marketing affiliate or third party for arranging the sale of production.

Whether these deductions can legally be charged to a royalty owner depends on the language of your lease. Many leases contain "free of cost" or "at the well" clauses that restrict or prohibit the operator from passing post-production costs through to the royalty interest. This is an area of significant litigation across producing states.

#Net Revenue Interest (NRI) / Decimal Interest

Your net revenue interest — sometimes called your decimal interest — represents your fractional share of production revenue. For example, a mineral owner with a 1/8th royalty in a 640-acre unit who owns 80 net mineral acres would have an NRI of approximately 0.01562500 (80/640 x 1/8).

This decimal should match what is recorded on your division order, which in turn should be traceable back to your deed and any pooling or unitization orders. Even a small error in the sixth or seventh decimal place can produce meaningful dollar differences over time when applied to high-volume production.

#Net Payment Calculation

The net payment is the bottom line — the amount of the check. The basic formula is:

Net Payment = (Gross Production x Price - Deductions) x NRI

Some operators calculate deductions before applying your decimal interest; others apply your interest to gross revenue first and then subtract your proportional share of deductions. The method should be consistent with your lease terms, and you should verify which approach your operator uses.

#Common Errors to Look For

Not every statement error is the result of bad intent. Large operators manage thousands of revenue interests across hundreds of wells, and clerical and systems errors are inevitable. But as the royalty owner, the burden of catching those errors falls on you.

#Incorrect Decimal Interest

This is the most fundamental error and one of the most common. Division order analysts sometimes miscalculate a decimal, particularly in complex title situations involving multiple conveyances, heirship, or pooled units that cross lease boundaries. Always verify your NRI against your own title work.

#Unauthorized or Excessive Post-Production Deductions

Operators sometimes deduct costs that are not permitted under the lease. The landmark Texas Supreme Court case Heritage Resources, Inc. v. NationsBank (1996) established that the terms of the lease control which costs can be deducted, and that royalty owners are not automatically responsible for post-production expenses absent clear lease language authorizing those deductions. If your lease contains a "free of cost" royalty clause and you are seeing transportation, gathering, or processing charges on your statement, you may have a valid claim for reimbursement.

Beyond unauthorized deductions, watch for deduction amounts that seem disproportionately high relative to the gross value of production. Gathering and transportation fees that consume 20% or more of gross revenue, for instance, warrant investigation.

#Wrong Pricing Benchmark

Your statement should reflect the actual price received for your production, or a price calculated in accordance with your lease terms. Some operators mistakenly apply a lower posted price when the actual realized price was higher, or they use a regional index that does not match the point of sale. Compare the price on your statement to publicly available benchmarks — WTI (West Texas Intermediate) for crude oil, Henry Hub for natural gas — keeping in mind that locational and quality differentials will cause your realized price to differ from these national benchmarks.

#Missing or Unreported Production Months

It is not uncommon for a royalty owner to skip a month's payment without explanation. This could be a timing delay, a minimum check threshold, or a genuine oversight. Cross-reference your payment history against state production records. In Texas, the Railroad Commission of Texas (RRC) publishes monthly production data by lease and well. Oklahoma's Corporation Commission (OCC) and New Mexico's Oil Conservation Division (OCD) provide similar public databases.

#Improper Severance Tax Calculations

Severance tax should be calculated on the correct gross value and at the correct rate. In Texas, where the oil severance tax is 4.6% and the gas severance tax is 7.5%, errors sometimes occur when an operator applies the gas rate to oil production or vice versa. Additionally, some wells qualify for reduced tax rates under state incentive programs (such as the Texas high-cost gas exemption or stripper well exemptions), and those reduced rates should be reflected on your statement if applicable.

#Gas Volume Unit Mismatches

Natural gas can be measured and reported in MCF (thousand cubic feet) or in MMBTU (million British thermal units). The difference matters because gas with a high BTU content will have a higher value per MCF than the per-MMBTU price would suggest, and vice versa. Ensure the volumes and prices on your statement use consistent units, and that any heating value adjustments (the BTU factor) are applied correctly.

#Step-by-Step Audit Process

You do not need to be a petroleum engineer or a CPA to audit your royalty statement. The following six-step process gives you a structured framework for catching the most common errors.

#Step 1: Verify Your Decimal Interest

Pull out your original deed, mineral conveyance, or lease agreement. Compare the interest described in those documents to the decimal on your most recent division order and on your royalty statement. If the property has been pooled or unitized, obtain a copy of the pooling order from the state commission and verify the unit's acreage and your proportional interest within it.

#Step 2: Cross-Reference Production Volumes

Look up the well's reported production on your state's oil and gas commission website. In Texas, the RRC Production Data Query allows you to search by API number or lease number. Compare the gross production volumes reported to the state against the volumes shown on your royalty statement. The numbers should be close, though minor differences can arise from measurement timing and allocation methods in multi-well units.

#Step 3: Compare Pricing to Benchmarks

For the production month in question, look up the average WTI spot price (for oil) or Henry Hub spot price (for gas) using the U.S. Energy Information Administration (EIA) website. Your realized price will differ from these benchmarks due to basis differentials, quality adjustments, and the specific terms of the operator's sales contract. But the benchmark gives you a sanity check. If WTI averaged $72 per barrel for the month and your statement shows a price of $55, you need to understand why.

#Step 4: Itemize and Challenge Deductions

List every deduction on your statement, calculate each one as a percentage of gross revenue, and then compare those deductions against the language of your lease. Key questions to ask:

• Does your lease permit the operator to deduct post-production costs from your royalty?
• Are the deduction categories consistent from month to month, or have new charges appeared?
• Are the deduction amounts reasonable? Benchmark them against publicly available pipeline tariff rates and processing fee schedules in your basin.

If your lease includes a "free of cost" or "at the well" royalty clause, any post-production deduction is potentially improper.

#Step 5: Recalculate the Net Payment

Using the gross production volumes, the stated price, the deductions, and your NRI, independently recalculate what you should have been paid. Work through the formula:

1. Multiply gross production by the price per unit to get gross revenue.
2. Subtract each deduction to get net revenue.
3. Multiply net revenue by your decimal interest.
4. Compare your calculated result to the check amount.

Any discrepancy beyond a rounding difference (a few cents) is worth investigating.

#Step 6: Document and Escalate

If you find an error, put your findings in writing. Send a certified letter to the operator's revenue or division order department identifying the well, the production month, the specific discrepancy, and the amount you believe is owed. Request a formal accounting under the terms of your lease. Most states, including Texas, have statutory deadlines within which an operator must respond to a written accounting request.

#When Errors Add Up

A $50 monthly underpayment might not seem worth the effort of an audit. But over a 25-year producing life, that single error amounts to $15,000 in lost revenue — before considering the time value of money. Now multiply that across several wells, or consider that the error may have persisted since the well's first production, and the numbers quickly become significant.

The challenge is that manual auditing is time-intensive. Pulling state production reports, tracking commodity prices, itemizing deductions, and recalculating payments for every well every month is simply not practical for most mineral owners, and even many operators with large portfolios struggle to keep pace.

This is precisely why automated reconciliation is transforming the way oil and gas revenue is managed. By systematically comparing royalty statement data against state production records, market pricing benchmarks, and lease terms, automated tools can flag discrepancies in real time rather than months or years after the fact.

#Related Reading

• Understanding Division Orders & Decimal Interest
• Oil & Gas Royalty Deductions Explained
• Catching Operator Errors: A 5-Point Reconciliation Checklist

#Take Control of Your Revenue

Reading and auditing your royalty statement is not optional — it is an essential part of protecting your mineral asset. The operators who produce from your land are managing complex, high-volume accounting systems, and errors are a structural reality of the industry. The only question is whether those errors are caught and corrected, or whether they quietly erode your revenue over time.

AGR's reconciliation agent was built to solve this exact problem. It ingests your royalty statements, cross-references production data and pricing benchmarks, flags deduction anomalies, and surfaces discrepancies automatically — giving you the audit rigor described in this guide without the manual effort.

Learn how AGR's reconciliation platform can protect your revenue.