XTO Energy 2023 Royalty Settlement: Gas Deductions and Separate Carbon Dioxide Royalty Claims

In the 2023 XTO Energy royalty settlement, the company agreed to pay $16 million to resolve allegations of improper gas deductions and unpaid carbon dioxide royalties. The case turns on what transportation and processing charges really covered, and whether a plant’s carbon dioxide production generated a royalty payment at all.

The Justice Department announced the settlement on November 1, 2023, over royalties owed on gas produced from federal and Native American lands. This page follows XTO’s separate gas and carbon dioxide allegations, while our explanation of how production becomes a royalty payment covers the wider accounting chain. For someone who knows the contracts, plant allocations or reporting decisions, the distinction between an inflated deduction and an unpaid product can be the beginning of the case.

What Did the XTO Energy 2023 Royalty Settlement Cover?

The XTO Energy 2023 royalty settlement covered costs deducted to make gas marketable, carbon dioxide transportation deductions and unpaid Castle Valley carbon dioxide royalties. The settlement agreement separates those allegations into four branches because the marketable-condition claims have different periods for onshore and Native American leases and for offshore leases.

Gas Deductions That Included the Cost of Making Gas Marketable

The Justice Department alleged that XTO knowingly deducted third-party transportation and processing payments that included the cost of putting gas in marketable condition. Its announcement explains the bargain behind the leases: companies can produce natural gas in exchange for royalties on its value, and lessees must make the gas marketable at no cost to the United States. The allegation concerns whose bill those preparation costs became when XTO calculated royalties.

For federal onshore and Native American leases, the agreement covers production months from January 1, 2009 through August 31, 2017. For federal offshore leases, it covers January 1, 2009 through July 31, 2011.

The agreement describes the challenged deductions as monetary or volumetric. A deduction could therefore enter the calculation as money or as gas volume, a distinction that matters when a processor’s statement is compared with the royalty calculation. We examine both the charge and how it moved through the account, because the allegation reaches beyond the label on an invoice.

Paying a third party was central to the Justice Department’s description. The alleged deductions included costs of making the gas marketable within payments described as transportation and processing. We see the upside-down bargain in the Justice Department’s allegation: the producer prepares its gas for sale. The mineral owner helps pay.

Carbon Dioxide Transportation Reduced the Gas Royalty Value

The carbon dioxide transportation allegation concerned a cost taken out of the value used to calculate federal gas royalties. The Justice Department said XTO knowingly and improperly deducted the cost of transporting carbon dioxide entrained in the gas, meaning carbon dioxide carried in the gas stream. The agreement places this branch on federal onshore leases, for production months from January 1, 2009 through June 30, 2016.

This allegation follows the contents of the stream as well as the transportation charge. Inlet composition, transportation contracts and cost allocations help connect what moved through the system to the expense deducted in reporting royalties. For an insider who knows the gas composition or the basis of a transport invoice, that connection can explain why a charge against gas revenue included a cost associated with carbon dioxide.

The accounting question is specific: which part of the transportation expense reduced the royalty value? We follow that allocation from the underlying charge into the reported deduction. A single transportation payment can contain the detail that the royalty total hides.

The Unpaid Carbon Dioxide Claim at Castle Valley

The Castle Valley allegation concerned royalties on carbon dioxide itself. The Justice Department said XTO failed to pay federal royalties owed on carbon dioxide produced at the Castle Valley Plant in Utah. The agreement identifies that carbon dioxide as product code 17 and covers production months from May 31, 2010 through March 31, 2016.

The agreement ties this allegation to a separate schedule of leases whose product was processed at Castle Valley. That makes the plant’s output and allocation records central to understanding the claimed shortfall: they connect the processed product to the leases that generated it. The Justice Department alleged that the royalty on that product went unpaid, a different problem from deducting a transportation expense when paying royalties on natural gas.

Someone who sees plant output may recognize this part of the story before someone who sees only a gas royalty total. We connect the product, the producing leases, the reported value and the payment account. In the Justice Department’s allegation, the carbon dioxide reached the plant but its royalty never reached the owner.

Interior’s Office of Natural Resources Revenue describes sales and royalty remittance reporting in its Minerals Revenue Reporter Handbook. Comparing a plant’s product allocations with its ONRR-2014 report connects what was produced to the royalty calculation and payment account. For an allegation like Castle Valley’s, that connection is the useful evidence behind an energy royalty claim: a product can appear in plant records without generating the royalty owed.

Is the Royalty Owed to the United States, a Tribe or a Private Owner?

The mineral owner’s interest determines who is owed the royalty; XTO’s settlement concerned federal and Native American interests. Its marketable-condition allegations covered both, while the Justice Department described the carbon dioxide transportation and Castle Valley claims as federal royalty matters. The agreement identifies federal onshore, federal offshore and Indian leases separately.

The lease and ownership records identify whose share is at issue, while plant allocations connect that interest to the production. ONRR’s revenue documentation includes federally administered Native American interests. Someone who knows the plant’s allocations can help trace the federal or Native American share through the royalty report, even when the same plant handles production for different owners.

XTO’s Agreement Also Addressed Prior-Period Reports

XTO’s agreement addressed the reported accounts as well as the settlement payment. It states that XTO had filed prior-period reports in a manner agreed with ONRR before the agreement was executed, and that ONRR had accepted those reports as an accurate and correct implementation of the agreement.

A revised report carries the account back to the production period being changed. The original, reversal and replacement lines show how the report changed, while the payment account shows the money applied. We examine those together when an insider knows that the production, deduction or product information reaching the royalty account differed from the underlying records.

The Marketable-Condition Pattern Extends Beyond XTO

The XTO announcement described $25 million recovered through a series of marketable-condition settlements since 2017. That figure includes XTO’s settlement. The repeated issue is a producer deducting costs that the Justice Department said belonged to making its gas marketable.

Devon Energy’s separate settlement announced in September 2021 concerned gas from federal lands in Wyoming and New Mexico. The Justice Department alleged that transportation and processing payments included costs of placing the gas in marketable condition. The parallel is the content of the deduction: an invoice can describe transportation or processing while including the preparation costs at the heart of the allegation.

Devon’s earlier royalty settlement involved different conduct. In its March 2012 announcement, the Justice Department described allegations involving Devon’s predecessor, including deductions for boosting gas to pipeline pressure and unreported gas used to fuel boosting compressors. That comparison shows why the equipment and the accounting both matter: a compressor’s cost and the gas it consumes can appear in different parts of the royalty calculation.

What a Royalty Insider Can Bring to a Whistleblower Case

A royalty insider may know how a cost was classified, which product a plant reported or how a prior-period adjustment changed the account. XTO’s settlement puts those distinctions in concrete terms: marketable-condition costs deducted from royalties, carbon dioxide transportation deducted from gas value, and royalties allegedly unpaid on a separately identified product. We work with the person who understands those decisions to connect them to the amount owed and what the company knew.

A whistleblower case under the False Claims Act can pay 15% to 30% of what the government recovers. Our work on energy whistleblower rewards starts with the royalty obligation and the conduct your information reveals.

You Know What Went Into the Deduction

If you know why a gas deduction grew or why carbon dioxide production never generated a royalty payment, talk with our whistleblower experts about what you saw. We bring the production and royalty accounting together, build the case with you, and bring in energy royalty whistleblower lawyers who understand the costs and reporting behind it. You have a partner from the first conversation through the pursuit of the recovery.