Oil prices have averaged materially higher in 2026 than in 2025, and plenty of mineral owners opened their statements expecting a bump. Instead the check was smaller, sometimes materially smaller. That is not necessarily an error and it is not necessarily theft. For owners whose income comes primarily from newer horizontal wells, one common explanation is that production decline is outweighing the benefit of higher commodity prices. This post walks through why that happens, shows a worked monthly royalty calculation at months 1, 12, and 24 with every assumption labeled, and gives you a four-point checklist to run before you call the operator.
Horizontal Decline Is Steeper Than Most Owners Expect
A vertical well drilled into a conventional reservoir thirty years ago might have declined 8 to 15% per year. A modern horizontal well in the Permian, SCOOP, STACK, Eagle Ford, or Haynesville behaves nothing like that. Modern horizontal wells in shale and tight formations commonly experience steep early production declines, often far greater than conventional vertical wells. In some plays, first-year declines of roughly 60% or more have been documented, although actual decline rates vary significantly by basin, formation, completion design, and individual well.
The reason is physics, not accounting. Hydraulic fracturing creates enormous initial flow by opening a dense network of fractures near the wellbore. Pressure in that stimulated rock drops quickly, and once it drops the well settles into a lower baseline that declines more gradually. As the well matures, the rate of decline generally moderates, although the timing and shape of that transition vary considerably by well and reservoir.
If your royalty income is weighted toward wells that came online in 2024 or 2025, you are riding the steepest part of that curve right now. For example, a 10% increase in realized oil price cannot offset a 65% decline in production volume. Valor manages roughly 500,000 wells across 32 states and 13 basins, and this pattern is a recurring question our mineral management team regularly encounters. For context on how royalty payments are calculated and what your decimal interest means, read How to Calculate Your Royalty Decimal Interest.
A Worked Example: Months 1, 12, and 24 on the Same Interest
Here is a simplified calculation using round numbers so you can plug in your own. Every assumption is labeled. This is illustrative, not a forecast for any specific tract.
Labeled assumptions:
- Initial production (month 1): 15,000 barrels of oil for the well that month
- First-year decline rate: 70% (so month 12 volume is 30% of month 1)
- Second-year decline rate: 35% (so month 24 volume is 65% of month 12)
- Realized oil price, month 1: $70 per barrel
- Realized oil price, month 12: $75 per barrel (price rose)
- Realized oil price, month 24: $72 per barrel
- Your decimal interest: 0.0015
Month 1 royalty: 15,000 x $70 x 0.0015 = $1,575
Month 12 royalty: Volume is 15,000 x (1 – 0.70) = 4,500 bbl. 4,500 x $75 x 0.0015 = $506.25
Month 24 royalty: Volume is 4,500 x (1 – 0.35) = 2,925 bbl. 2,925 x $72 x 0.0015 = $315.90
In this simplified example, the decline in production more than offsets the higher oil price. Price went up between month 1 and month 12. The check still fell by roughly 68%.
Four Things to Check When a Royalty Check Drops
Before you assume the operator shorted you, work through these four variables in order. Three you can check from your own statements. The fourth usually requires a records review.
1. Volume. Compare the barrels of oil and MCF of gas on the current statement to the prior few months and to the first full month of production. A gradual decline may be consistent with normal well depletion, particularly on a newer horizontal well. If volumes drop sharply in a single month, say 90% or more, the well may have been shut in, choked back, or had a mechanical issue. State production records can provide an independent point of comparison, although reporting formats and timing vary. In Texas, for example, oil production is generally reported at the lease level rather than by individual well, and preliminary data can later be revised. For a guide to reading production activity on your acreage, read How to Read Oil and Gas Activity on Your Acreage.
2. Realized price. The number on your check is not NYMEX. It is what the operator actually sold the barrel for at the lease, net of transportation differentials and gas processing. Compare your realized price to published basin benchmarks for the production month. A persistent gap that cannot be explained by location or quality differences deserves a conversation. For a full explanation of how Henry Hub and WTI prices translate to your actual check, read Henry Hub vs. WTI: Which Price Actually Drives Your Royalty Check?
3. Deductions. Post-production costs including gathering, processing, compression, dehydration, and marketing can appear as separate line items or as a lower realized price. The lease and applicable law determine whether and how particular post-production costs may affect royalty payments. If deductions as a percentage of gross have risen sharply, pull the lease and read the royalty clause carefully. For a full explanation of how cost-free language interacts with what actually shows up on your check, read Cost-Free Royalty Clauses: Why You Still See Deductions on Your Check.
4. Decimal interest. Your decimal can change when the underlying ownership, unit configuration, tract participation, pooling allocation, title determination, or other inputs to the calculation change. When an ownership interest is conveyed or distributed, a change in payment decimal may result in updated division-order or owner-relations documentation that does not always arrive before the first check with the new interest. For a guide to verifying your decimal against your lease and unit size, read How to Calculate Your Royalty Decimal Interest.
When the Math Does Not Reconcile
If you work the four-point check and the numbers still do not line up, volume looks right, realized price is in the ballpark, deductions have not changed, and the decimal matches your most recent division order, that is when a professional review earns its keep. Potential causes can include title discrepancies, missing or misapplied interests, suspense balances, prior-period adjustments, or other accounting or ownership issues.
Valor has recovered more than $32 million in missing income for mineral owners, with statement reconciliation, ownership research, regulatory records, and lease review among the tools used to identify discrepancies. Our clients span 32 states and generate roughly $650 million in annual revenue in aggregate. The same reconciliation principles can be applied to both individual mineral interests and complex multi-state portfolios. The work is handled by CPAs, Certified Professional Landmen, and Certified Mineral Managers — the same Valor team you would meet if you called in. Valor has also completed a SOC 1 Type II examination, providing independent assurance over controls relevant to the services covered by the report, which matters when a bank, trust, or audit committee needs assurance about the numbers.
What to Do Before Next Month’s Check Arrives
If much of your royalty income comes from newer horizontal wells, declining production from those wells may continue to put downward pressure on payments even when commodity prices are stable or rising. The good news is that as many unconventional wells mature, the rate of production decline tends to moderate from the steep early-life decline, although the timing and magnitude vary by well. Additionally, wells in which your interest participates may create new production and royalty income depending on the unit, ownership, lease terms, and development plan.
In the meantime, keep three habits. Save every check stub and every division order. Review available state production records periodically and compare them with your royalty statements, recognizing that regulatory production data may be reported at the lease, well, or other reporting level depending on the state and property. And when a check moves significantly in a single month without an obvious price explanation, write down the question while it is fresh. It is much easier to resolve a discrepancy from the month it happened than from two years later. For help building that discipline across a full mineral portfolio, see how Valor approaches ongoing administration on our mineral management overview.
Contact Valor Today
If your 2026 checks are falling and you want a second set of eyes on the volume, price, deductions, and decimal before you confront the operator, Contact Valor today for a free, no-obligation review. Our royalty management team of CPAs, CPLs, and Certified Mineral Managers runs this reconciliation every day across 32 states and 13 basins. We handle royalty audits and statement reviews for mineral owners across Oklahoma, Texas, and 30 other states.
The information provided by Valor in this blog is for general informational purposes only and is not intended 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 attorney in your state.
Key Takeaways
- Expect first-year horizontal declines of 60 to 75%, which routinely overwhelm single-digit price gains. A rising price tape does not guarantee a rising check on a well less than two years old.
- Run the four-point check, volume, realized price, deductions, and decimal, before concluding your check is wrong. Three of the four you can verify from your own statements.
- Compare your reported volumes to state regulator filings at least once a year. The RRC and OCC publish production data that lets you confirm whether the operator reported accurately.
- Save every division order. An uncommunicated decimal change is one of the most common causes of a surprise drop that has nothing to do with price or production.
- Escalate to a professional review when the math still does not reconcile after you have worked the checklist. The discrepancy is usually real and usually recoverable.