Behind the Payout: Cross Timbers Trust Navigates a Turbulent Energy Market

DALLAS, TX – June 18, 2026 – Argent Trust Company, trustee for the Cross Timbers Royalty Trust (NYSE: CRT), announced a June cash distribution of $0.044186 per unit. While any payout is welcome news for income-focused investors, the details behind this figure paint a complex picture of the operational and market crosswinds buffeting this and similar energy-focused investment vehicles. The announcement underscores a challenging reality: rising oil prices were offset by falling production volumes and a persistent drag from operational costs, offering a stark case study in the volatility inherent in royalty trusts.

Decoding the Distribution for Unitholders

For unitholders, the monthly distribution is the primary measure of the trust's health. The June payout, payable on July 15 to unitholders of record as of June 30, reflects a significant increase from the prior month's $0.029624 per unit. However, placing this single data point in a broader context reveals a pattern of significant volatility and a general downward trend. Year-to-date distributions for 2026 now total approximately $0.18 per unit, a pace that lags far behind previous years. The trust distributed $0.75 per unit in 2025 and $0.95 in 2024, both stark declines from the $1.92 per unit paid out during the commodity boom of 2023.

This volatility is a core feature, not a bug, of royalty trusts. Unlike traditional corporations, these entities are passive financial instruments designed to pass income from underlying oil and gas properties directly to investors. They don't operate wells, employ staff, or reinvest profits into acquiring new assets. This structure allows them to avoid corporate-level taxation, but it also means their fortunes are directly chained to the fluctuating prices of commodities and the natural decline of their underlying reserves.

Investors are often drawn to trusts like CRT for their potential high yields and unique tax advantages, such as the depletion allowance, which can shield a portion of the income from taxes. However, as one financial advisor specializing in energy investments noted, "Investors must understand they are buying a finite, depleting asset. The income stream is not perpetual, and its size is dictated almost entirely by external market forces and the operational efficiency of the producer."

A Tale of Two Commodities

The latest distribution is based on sales from May, which saw a divergence in the performance of oil and gas. The trust's realized oil price jumped to $88.05 per barrel from $77.14 in the prior month, reflecting a stronger market. This price appears to be in line with the lower-to-mid range of West Texas Intermediate (WTI) crude benchmarks for May. However, this positive pricing was undercut by a 10% drop in sales volume, down to 9,000 barrels from 10,000 barrels previously.

The story for natural gas was less favorable. Both the realized price and sales volume declined. The average price fell to $4.30 per Mcf from $4.98, while volumes plummeted over 40% to 27,000 Mcf from 47,000 Mcf. Interestingly, the trust's realized gas price continues to command a significant premium over the Henry Hub spot price, which averaged just under $3.00/MMBtu in May. This premium suggests favorable regional pricing or legacy contracts, but the sharp drop in volume erased any benefit, contributing to the mixed overall results.

This dynamic—where price gains in one commodity are negated by volume declines or weakness in another—highlights the operational tightrope the trust walks. Production levels are not entirely within the operator's control, subject to natural well decline rates and unforeseen operational issues.

The Persistent Drag of 'Excess Costs'

Perhaps the most significant long-term headwind detailed in the announcement is the issue of 'excess costs'. These costs arise from the trust's 75% net profits interests in certain working interest properties in Texas and Oklahoma, which are operated by XTO Energy, a subsidiary of ExxonMobil. Unlike a pure royalty interest, a working interest exposes the trust to a share of the production and development costs. When these expenses exceed the revenue from those specific properties, the deficit is recorded as an 'excess cost'.

This month, XTO Energy advised that excess costs on the Texas properties increased by $25,000, bringing the cumulative total to a staggering $5.95 million. For the Oklahoma properties, there was a recovery of $136,000 in costs. However, this recovery wasn't enough to generate a profit, and consequently, no proceeds from these Oklahoma interests were included in this month's distribution. The remaining cumulative excess costs for Oklahoma stand at $842,000.

These accumulating costs act as a direct lien on future income. Until these multi-million-dollar balances are paid down by future revenues from their respective properties, they will continue to suppress the total cash available for distribution. This highlights the critical role of the operator, XTO Energy, in managing expenses on these mature assets, where the margin between profit and loss can be razor-thin.

A Case Study in a Shifting Energy Landscape

Cross Timbers Royalty Trust's current situation serves as a powerful illustration of the risks and rewards of investing in the energy royalty sector. Analyst sentiment on CRT is generally cautious, with most ratings falling into the 'Hold' category, reflecting the uncertainty clouding its future earnings. The fundamental challenge for all U.S. royalty trusts is their status as depleting assets; without the ability to acquire new properties, their production base is in a state of managed decline.

This structural reality makes them highly sensitive to the broader energy market. The recent drop in WTI crude prices below $75 per barrel in June, a development occurring after the sales period for this distribution, suggests potential headwinds for the trust's payouts in the coming months. For investors, the appeal of a high yield must be weighed against this inherent volatility and the long-term decline of the underlying asset base.

The trust's performance is a constant balancing act between commodity prices, production volumes, and the careful management of operational costs on aging wells, a complex equation that will continue to define its value to unitholders.