Business Context and Reporting Period
Company: Black Stone Minerals, L.P. (BSM)
Filing Type: Form 10-Q (Unaudited)
Period Ended: March 31, 2025
Business Overview: BSM is a publicly traded Delaware limited partnership owning oil and natural gas mineral and royalty interests across 41 U.S. states. The company operates in a single segment, generating revenue from hydrocarbon sales and lease bonuses. As of March 31, 2025, the partnership held interests in approximately 71,000 producing wells.
Key Financial Metrics
| Metric (in thousands, except per unit) | Q1 2025 | Q1 2024 |
|---|---|---|
| Total Revenue | $59,252 | $105,493 |
| Net Income (Loss) | $15,948 | $63,927 |
| Net Income Attributable to Common Units | $8,582 | $56,560 |
| Earnings Per Unit (Diluted) | $0.04 | $0.27 |
| Adjusted EBITDA | $82,167 | $104,117 |
| Distributable Cash Flow | $73,677 | $96,388 |
| Cash Flow from Operating Activities | $64,835 | $104,460 |
| Cash and Cash Equivalents (End of Period) | $2,424 | $40,456 |
| Total Debt (Credit Facility) | $63,000 | $25,000 |
| Available Borrowing Capacity | $312,000 | $350,000 |
Material Changes vs. Prior Period
- Revenue Decline: Total revenue decreased 43.8% to $59.3 million, driven primarily by a $56.0 million loss on commodity derivative instruments compared to an $11.3 million loss in Q1 2024. Oil sales dropped 29.7% due to lower volumes and prices, while natural gas sales increased 38.6% due to higher realized prices.
- Production Volumes: Total production equivalents decreased 13.0% to 3,192 MBoe. Oil production fell 22.4% (716 MBbls vs. 923 MBbls), while natural gas production declined 9.8% (14,853 MMcf vs. 16,470 MMcf).
- Derivative Impact: The company recognized $52.4 million in unrealized losses and $3.6 million in realized losses on derivatives in Q1 2025, significantly impacting net income compared to Q1 2024.
- Debt Utilization: Borrowings under the Credit Facility increased from $25.0 million to $63.0 million to fund acquisitions and operations.
- Acquisitions: The company acquired mineral and royalty interests for $14.2 million in Q1 2025, funded by $10.3 million in cash and $3.9 million in equity issuance.
Outlook, Risks, and Management Commentary
- Commodity Hedging: As of March 31, 2025, BSM has hedged a portion of expected production for the remainder of 2025 and 2026 using fixed-price swaps. Oil swaps average $71.22/Bbl for 2025 and $64.82/Bbl for 2026. Natural gas swaps average $3.36-$3.45/MMBtu for 2025 and $3.67/MMBtu for 2026.
- Development Activity: In the Shelby Trough, Aethon Energy is on track to turn 17 additional wells to sales in 2025. In the Permian Basin, a large operator has spud 24 of 35 planned wells, with production expected in late 2025 and 2026.
- Liquidity and Distributions: The Board approved a distribution of $0.375 per common unit for Q1 2025, payable May 15, 2025. The company maintains a $150 million unit repurchase program, though no repurchases were made under this program in Q1 2025 (221,000 units were withheld for taxes).
- Risks: Key risks include volatility in oil and natural gas prices, reliance on third-party operators for drilling activity, and potential impacts of trade policies and tariffs on global demand. The company notes that natural gas prices rose in Q1 2025 due to cold weather and new LNG exports, while oil prices faced pressure from trade policy concerns.
Investor Verification Checklist
- Derivative Exposure: Verify the impact of the $56 million derivative loss on future cash flows and the specific terms of open swap contracts for 2025-2026.
- Production Trends: Confirm the sustainability of the 22.4% decline in oil production volumes and the timeline for new wells in the Permian and Shelby Trough to come online.
- Debt Covenants: Review compliance with the Credit Facility covenants, specifically the debt-to-EBITDAX ratio (currently compliant) and the borrowing base redetermination scheduled for October 2025.
- Preferred Unit Obligations: Note the $7.4 million quarterly distribution obligation on Series B preferred units (9.8% annual rate) which must be paid before common unit distributions.
- Acquisition Strategy: Assess the accretive nature of the $14.2 million Gulf Coast acquisitions and subsequent $21.4 million post-quarter acquisitions.