Business Context and Reporting Period
Company: Black Stone Minerals, L.P. (BSM)
Filing Type: Form 10-K (Annual Report)
Reporting Period: Fiscal year ended December 31, 2025
Business Overview: BSM is a publicly traded Delaware limited partnership and one of the largest owners of oil and natural gas mineral interests in the U.S. The company holds non-cost-bearing mineral and royalty interests in approximately 16.9 million gross acres across 41 states, including major basins such as the Permian, Haynesville/Bossier, and Bakken/Three Forks. It also holds non-operated working interests. The company's strategy focuses on maximizing value through active asset management and organic growth, with a significant portion of cash flow distributed to unitholders.
Key Financial Metrics
| Metric | 2025 | 2024 |
|---|---|---|
| Total Revenue | $469.9 million | $433.7 million |
| Net Income | $299.9 million | $271.3 million |
| Net Income Attributable to Common Units | $270.5 million | $241.9 million |
| Adjusted EBITDA | $337.4 million | $383.2 million |
| Distributable Cash Flow | $300.0 million | $351.7 million |
| Cash Flow from Operating Activities | $310.2 million | $389.0 million |
| Debt Outstanding (Credit Facility) | $154.0 million | $25.0 million |
| Borrowing Base | $580.0 million | $580.0 million |
| Proved Reserves (Total MBoe) | 54,845 | 57,380 |
| Production (Total MBoe) | 12,632 | 14,103 |
| Realized Price (Oil $/Bbl) | $64.24 | $74.61 |
| Realized Price (Gas $/Mcf) | $3.41 | $2.51 |
Material Changes vs. Prior Period
- Revenue Mix: Total revenue increased 8.4% year-over-year. This was driven by a $33.7 million increase in natural gas revenue (due to higher realized prices) and a $8.9 million increase in lease bonus income. These gains were partially offset by a $59.7 million decrease in oil revenue due to lower production volumes and lower realized oil prices.
- Derivative Gains: The company recognized a $47.6 million gain on commodity derivative instruments in 2025, compared to a $5.7 million loss in 2024. This included $11.0 million in realized gains and $36.6 million in unrealized gains.
- Production Decline: Total production volumes decreased 10.4% to 12,632 MBoe. Oil production fell 9.6% and natural gas production fell 10.7%, primarily due to natural decline rates in the Austin Chalk, Bakken/Three Forks, and Haynesville/Bossier plays.
- Expense Increases: Exploration expense surged 581.3% to $18.6 million, primarily due to seismic data acquisition costs for the Shelby Trough area. Interest expense increased 187.2% to $8.9 million due to higher average outstanding borrowings.
- Reserve Changes: Total proved reserves decreased 4.4% to 54,845 MBoe. While extensions and discoveries added 5,064 MBoe of proved undeveloped reserves (PUDs), production and revisions resulted in a net decrease. PUDs now represent 12% of total reserves.
Guidance, Outlook, and Risks
Management Commentary & Outlook: Management expects to distribute a substantial majority of cash generated from operations. The company is focused on organic growth through development agreements in the Shelby Trough (Haynesville) and Permian Basin. In 2025, the company entered into Joint Exploration Agreements (JEAs) with Aethon, Revenant, and Caturus to accelerate drilling in East Texas. The company does not provide specific forward-looking financial guidance but notes that future results depend heavily on commodity prices and operator activity.
Key Risks & Contingencies:
- Commodity Price Volatility: Revenue is highly sensitive to oil and natural gas prices. While the company hedges a portion of its production (93% of oil and 100% of gas for 2026), unhedged exposure remains.
- Operator Dependence: As a non-operator, BSM relies on third-party operators for drilling and production. Delays or capital constraints at operators (e.g., in the Shelby Trough) could impact production growth.
- Debt Covenants: The Credit Facility requires a maximum debt-to-EBITDAX ratio of 3.5:1.0 and a current ratio of 1.0:1.0. Distributions are restricted if these covenants are breached or if availability falls below 10% of commitments.
- Regulatory & Environmental: Risks include potential changes in hydraulic fracturing regulations, methane emission rules, and climate change legislation which could increase costs or restrict operations.
- Preferred Units: Series B cumulative convertible preferred units have priority on distributions. The distribution rate is currently 9.8% per annum.
Investor Verification Checklist
- Operator Drilling Activity: Verify the progress of drilling commitments under the new JEAs with Aethon, Revenant, and Caturus in the Shelby Trough to ensure production replacement.
- Commodity Hedging: Review the specific terms and settlement dates of the 2026 and 2027 hedging positions to understand revenue protection levels.
- Debt Utilization: Monitor the utilization of the $580 million borrowing base, as outstanding debt increased significantly to $154 million in 2025.
- Reserve Revisions: Track the conversion of Proved Undeveloped Reserves (PUDs) to developed reserves, as 12% of the reserve base is currently undeveloped.
- Preferred Unit Redemption: Note the agreement with Series B preferred holders not to exercise redemption options until November 2027, which impacts future capital flexibility.