Business Context and Reporting Period
Company: Black Stone Minerals, L.P. (BSM)
Filing Type: Form 10-Q (Unaudited)
Reporting Period: Quarter and six months ended June 30, 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 June 30, 2025, the partnership held interests in approximately 71,000 producing wells.
Key Financial Metrics
| Metric (in thousands, except per unit) | Q2 2025 | Q2 2024 | 6M 2025 | 6M 2024 |
|---|---|---|---|---|
| Total Revenue | $159,494 | $109,624 | $218,746 | $215,117 |
| Net Income | $120,028 | $68,322 | $135,976 | $132,249 |
| Net Income Attributable to Common Units | $112,661 | $60,956 | $121,243 | $117,516 |
| Diluted Earnings Per Unit | $0.53 | $0.29 | $0.57 | $0.56 |
| Operating Cash Flow (6M) | $145,311 | $204,845 | ||
| Adjusted EBITDA (6M) | $166,318 | $204,364 | ||
| Debt Outstanding (Credit Facility) | $99,000 | $25,000 | $99,000 | $25,000 |
| Cash and Equivalents | $2,519 | $2,519 | $2,519 | $26,669 |
| Distributions per Common Unit (6M) | $0.7500 | $0.8500 | ||
Material Changes vs. Prior Period
- Revenue Composition: Total revenue for Q2 2025 increased 45.5% year-over-year, driven primarily by a $52.8 million gain on commodity derivative instruments compared to a $5.5 million loss in Q2 2024. Excluding derivatives, revenue from contracts with customers decreased 7.3% due to lower oil sales.
- Production Volumes: Total production equivalents decreased 14.4% in Q2 2025 (3,148 MBoe) compared to Q2 2024 (3,678 MBoe). Oil volumes dropped 9.4%, while natural gas volumes fell 16.1%.
- Commodity Prices: Realized oil prices decreased 16.6% to $64.67/Bbl, while realized natural gas prices increased 51.1% to $3.37/Mcf.
- Debt Utilization: Borrowings under the Credit Facility increased from $25.0 million at year-end 2024 to $99.0 million at June 30, 2025, resulting in higher interest expense ($2.3 million in Q2 2025 vs. $0.6 million in Q2 2024).
- Acquisitions: The company acquired mineral and royalty interests for $45.4 million in the first half of 2025, funded by $38.0 million in cash and $7.4 million in equity.
Outlook, Risks, and Management Commentary
- Development Activity: Management highlights active drilling in the Shelby Trough (Aethon Energy) and Haynesville (EXCO Resources). A new Joint Exploration Agreement (JEA) with Revenant Energy covers 270,000 gross acres with escalating well commitments starting in 2026.
- Hedging Strategy: As of June 30, 2025, the company has hedged portions of expected production for the remainder of 2025 and all of 2026 using fixed-price swap contracts. Oil swaps average $71.22/Bbl for Q3-Q4 2025 and $64.80/Bbl for 2026. Natural gas swaps average $3.45/MMBtu for Q3-Q4 2025 and $3.67/MMBtu for 2026.
- Liquidity: The company maintains a $1.0 billion Credit Facility with a borrowing base of $580.0 million. Unused availability was $276.0 million as of June 30, 2025. The company is in compliance with all financial covenants.
- Distributions: The Board approved a distribution of $0.30 per common unit for Q2 2025, payable August 14, 2025. This represents a reduction from the $0.3750 per unit paid in the prior quarter.
- Risks: Key risks include volatility in oil and natural gas prices, reliance on third-party operators for drilling activity, and potential changes in trade policies affecting demand. The filing notes that natural gas prices were supported by cold weather in Q1 2025, but future pricing remains uncertain.
Investor Verification Checklist
- Derivative Impact: Verify the sustainability of Q2 2025 net income, which was heavily influenced by a $52.8 million unrealized gain on derivatives, contrasting with a loss in the prior year.
- Production Decline: Assess the long-term impact of the 14.4% year-over-year decline in production volumes, particularly in the Permian Basin and Haynesville plays.
- Debt Levels: Monitor the increase in Credit Facility utilization to $99.0 million and the associated rise in interest expense.
- Distribution Policy: Confirm the rationale for the reduction in the quarterly common unit distribution from $0.3750 to $0.3000.
- Acquisition Integration: Review the performance of the $45.4 million in Gulf Coast acquisitions made in the first half of 2025.