Gas growth, partner risk
- BSM is a royalty owner, so operators pay most drilling costs while BSM collects a share of production revenue.
- Q1 2026 production was 37.0 MBoe per day, up 4.2% from the prior year period.
- The long-term growth plan is centered on the Haynesville and Shelby Trough gas acreage.
- Revenant had a loss of well control incident, and BSM is still assessing the effect on 2026 well commitments.
- The balance sheet looks stronger than the stock's valuation setup, so the price paid matters.
A gas ramp with a real hitch
The bull case is simple. BSM owns mineral and royalty interests across many U.S. basins. Its best growth setup is in the Haynesville and Shelby Trough, where long-term drilling deals with Adamas, Revenant, and Caturus could turn undeveloped acreage into rising gas royalties.
Q1 2026 helped the bull case on current output. Total production was 37.0 MBoe per day, up 4.2% from the same period in 2025. Management also kept its 2026 production guide after a strong start, helped by Haynesville and Shelby Trough gas activity and Permian oil volumes.
The bear case is now more concrete. Revenant spud two wells in Q1, and one later had a loss of well control incident. The 10-Q says BSM is assessing the impact on Revenant's first program year development plan and well commitments. That matters because BSM depends on other companies to drill.
This is why the setup is mixed. The acreage could be worth more if the gas drilling plan works, but the stock does not look cheap enough to ignore delays. The next few quarters need to show that Revenant's issue is a speed bump, not a reset of the growth timeline.
Paid when others drill
BSM owns mineral and royalty rights. It leases those rights to exploration and production companies. Those operators drill, complete, and run the wells. BSM then gets royalties, which are a cut of the oil and gas sales.
That model can be very cash generative because many royalty interests are non-cost-bearing, meaning BSM does not pay the main well costs. It also earns lease bonus payments when it signs leases. In Q1 2026, lease bonus and other income was $6.4 million.
The weak point is control. BSM can sign agreements and shape incentives, but it usually cannot force perfect field execution. If an operator slows drilling, has a safety event, loses access to capital, or sees poor well results, BSM feels it through lower volumes and lower royalty checks.
BSM also buys more mineral interests. In Q1 2026 it bought $11.5 million of mostly non-producing mineral and royalty interests, and it had completed $251.0 million of acquisitions from September 2023 through March 2026, mainly around the expanding Shelby Trough area.
What BSM gets paid on
Natural gas and NGL royalties
This is the main long-term growth lane. Q1 2026 natural gas and NGL sales were $63.4 million, and the Haynesville and Shelby Trough are the key basins to watch.
Oil and condensate royalties
Oil and condensate still matter a lot to revenue. Q1 2026 oil and condensate sales were $54.1 million, helped by higher Permian and Eagle Ford royalty volumes.
Lease bonus and other income
Lease bonuses are upfront payments when BSM leases mineral rights. They can move around by quarter because they depend on deal timing and operator interest.
Mineral acquisitions
BSM keeps adding mineral and royalty interests to grow the base. Recent buying has focused mainly on the expanding Shelby Trough area.
3D seismic data
BSM is funding large 3D seismic surveys in the Shelby Trough and Haynesville expansion area. This could help attract drilling, but it adds capital risk to a normally capital-light model.
Q1 revenue mix
Mix is based on Q1 2026 revenue from contracts with customers in the 10-Q, excluding derivative gains and losses. BSM does not report clean basin segment shares, so this view uses disclosed product revenue lines.
What could break the plan
Revenant drilling delay
High impact · Medium oddsRevenant is tied to a core Shelby Trough growth program. One of its Q1 2026 wells had a loss of well control incident, and BSM is still assessing the effect on the first program year and related commitments. A long delay would push part of the expected gas ramp into later periods.
Operator dependence
High impact · Medium oddsBSM does not operate the wells that drive most of its production. Operators decide how fast to drill, what capital to spend, and how to handle field problems. If Adamas, Revenant, Caturus, Coterra, or other partners slow down, BSM's royalty income can lag the acreage story.
Natural gas price weakness
High impact · Medium oddsMost of BSM's production volumes come from natural gas. Lower gas prices can reduce royalty revenue and make operators less eager to drill. Some Shelby Trough agreements can also suspend drilling obligations if gas prices fall below set levels.
Permian timing risk
Medium impact · Medium oddsThe Permian helps support oil and liquids cash flow. Management has sounded careful on broader Permian development because of pricing, and some volumes are expected in the second half of 2026 and first half of 2027. A slower Permian would leave more pressure on the gas ramp.
Seismic spending does not pay off
Medium impact · Medium oddsBSM is funding two large 3D seismic surveys over about 360,000 gross acres. That is not typical for its capital-light royalty model. The risk is that the surveys do not lead to enough new drilling or data value to justify the spending.
In one breath
What does Black Stone Minerals do?
Black Stone owns mineral and royalty interests in oil and gas properties. It leases those rights to operators and gets paid when oil, gas, or natural gas liquids are produced.
Why is the Haynesville important for BSM?
The Haynesville and Shelby Trough are the center of BSM's long-term natural gas growth plan. Development deals with Adamas, Revenant, and Caturus put about 500,000 gross acres into active development.
What is the Revenant issue?
Revenant spud two wells in Q1 2026, and one had a loss of well control incident in April 2026. BSM says it is assessing the impact on Revenant's first program year drilling plan and well commitments.
Is BSM more exposed to oil or natural gas?
Production volumes are weighted more toward natural gas, but revenue can swing with prices. In Q1 2026, natural gas and NGL sales were larger than oil and condensate sales.