Texas Pacific Land Corporation

Oil and gas royalties, which represented roughly 52% of FY2025 revenue, fluctuate with wellhead prices and drilling activity, as evidenced by the FY2021-to-FY2022 revenue decline. The absence of contracted backlog or subscription structures means revenue visibility is driven by commodity cycles rather than locked-in agreements.

Revenue splits between oil and gas royalties (~52% of FY2025), water services and produced-water royalties (~39%), and surface easements and sales (~9%), but all three streams trace back to the same driver: hydrocarbon extraction activity in the Permian Basin. An activity slowdown or oil price decline would pressure all segments simultaneously, with no genuinely uncorrelated revenue offset.

Substantially all revenue originates from the Permian Basin in West Texas, with no material revenue from outside the region. A single-basin footprint means any disruption to Permian activity, including local infrastructure bottlenecks, water disposal regulation changes, or regional production declines, would affect every revenue line without geographic offset.

TPL bears no drilling or extraction costs: royalties and surface fees flow from operator activity without proportional capital expenditure, generating adjusted EBITDA margins near 84% in FY2025. This structural cost profile has been sustained across FY2020-FY2025, including through the FY2020 oil-price shock, demonstrating durable operating leverage from the asset-light royalty model.

Royalties from actively producing Permian wells are inherently recurring as long as wells produce, which can span decades, and water and surface services are operationally essential to operators who cannot easily relocate. However, no contractual subscription or multi-year pricing guarantees exist; the revenue base is transactional and commodity-linked rather than contracted.