Company Overview - Black Stone Minerals, L.P. is one of the largest owners and managers of oil and natural gas mineral interests in the United States, generating revenue primarily from royalty payments across approximately 16.8 million gross acres [7] - The company reported a revenue of $400.98 million and a net income of $270.47 million for the trailing twelve months (TTM) [4] - As of March 21, 2026, the stock price experienced a 1-year change of -0.39% [4] Transaction Summary - Luke Stevens Putman, SVP, General Counsel, and Secretary of Black Stone Minerals, sold 30,276 common units for a transaction value of approximately $461,585 on March 5, 2026 [1][2] - This sale resulted in a complete reduction of Putman's direct holdings in the traded share class to zero [6] - The transaction occurred when Black Stone Minerals units closed at $15.44, with a one-year total return of 16.1% [6] Market Context - On the day of the sale, the stock price ranged from $15.23 to $15.45, with a 52-week range of $11.78 to $15.49 [7] - The company has a market capitalization of $3.2 billion [5] - The average trading volume was 412,000, while the actual volume on the day of the transaction was 582,000 [7] Investment Considerations - Investors should be aware that Black Stone Minerals operates as a Master Limited Partnership (MLP), where purchasing common units is akin to owning common shares but with different legal implications [8] - MLPs typically pay cash distributions instead of dividends, which can be higher due to the avoidance of corporate-level taxation [9] - Current political tensions may make Black Stone Minerals stock appealing, as global oil supply risks and rising gas prices in the U.S. could benefit the stock [11]

Group 1 - Black Stone Minerals (BSM) is anticipating a production increase in 2026, expecting to reach an average of approximately 34,500 BOEPD after a decline to around 32,100 BOEPD in Q4 2025 [1] - The article highlights the expertise of Aaron Chow, who has over 15 years of analytical experience and is recognized as a top-rated analyst on TipRanks, with a focus on the energy sector [1]

Drilling Commitments and Production - Aethon expects to drill a total of 14 wells in the current program year, with 6 wells already spud and 5 wells from the previous year expected to be turned to sales in early 2026[90]. - Revenant's drilling commitments include a total of 175,000 gross lateral feet by 2030 and beyond, with a minimum of 105,000 feet in Program Year 5[94]. - Caturus has minimum net lateral-foot commitments escalating to 25,200 feet by 2031 and beyond, starting with 6,000 feet in 2026[96]. - The company has entered into multiple Joint Exploration Agreements (JEAs) with Aethon, Revenant, and Caturus, focusing on expanding drilling commitments and development rights[89][91][95]. - The company’s total gross well count as of December 31, 2025, was 4,610 for Bakken/Three Forks and 1,588 for Haynesville/Bossier[3]. Production and Reserves - Average daily production for mineral and royalty interests in 2025 was 33,256 Boe/d, a decrease from 36,577 Boe/d in 2024[101]. - The Bakken/Three Forks, Haynesville/Bossier, and Permian plays accounted for 73% of the company's aggregate production for the year ended December 31, 2025[102]. - As of December 31, 2025, estimated proved reserves include 16,636 MBbls of oil and 229,257 MMcf of natural gas, totaling 54,845 MBoe[114]. - Estimated proved undeveloped reserves (PUDs) as of December 31, 2025, comprise 395 MBbls of oil and 37,625 MMcf of natural gas, or 6,666 MBoe[115]. - New PUD reserves totaling 5,064 MBoe were added during the year ended December 31, 2025, primarily from development activities in the Haynesville/Bossier play and the Permian Basin[116]. Production Metrics - The company’s average daily production for the Haynesville/Bossier resource play was 15,571 Boe/d in 2025, down from 18,476 Boe/d in 2024[3]. - The average daily production for the Bakken/Three Forks resource play was 3,074 Boe/d in 2025, compared to 3,282 Boe/d in 2024[3]. - Oil and condensate production decreased to 3,259 MBbls in 2025 from 3,606 MBbls in 2024, a decline of 9.6%[121]. - Natural gas production fell to 56,237 MMcf in 2025, down 10.5% from 62,984 MMcf in 2024[121]. - Average daily production decreased to 34.6 MBoe/d in 2025, compared to 38.5 MBoe/d in 2024, reflecting a 10.1% decline[121]. Financial Performance - Realized prices for oil and condensate dropped to $64.24 per Bbl in 2025, down 13.4% from $74.61 per Bbl in 2024[121]. - Unit cost per Boe for production costs and ad valorem taxes decreased to $3.09 in 2025 from $3.52 in 2024, a reduction of 12.2%[121]. - The percentage of proved developed reserves was 87.8% as of December 31, 2025, down from 94.6% in 2024[114]. - The company incurred $0.6 million in drilling, completing, and recompleting wells that were not classified as PUDs as of December 31, 2024[118]. Acreage and Ownership - The total acreage as of December 31, 2025, is 16,931,851 gross acres, with a mineral interest ownership average of 43.4%[99]. - The Gulf Coast region has a total of 8,049,498 gross acres, with a mineral interest ownership average of 51.7%[99]. - The Southwestern U.S. region has 2,773,819 gross acres, with a mineral interest ownership average of 25.4%[99]. - The Rocky Mountains region has 2,123,454 gross acres, with a mineral interest ownership average of 15.4%[99]. - Total acreage for mineral and royalty interests amounted to 20,326,612 acres as of December 31, 2025, with 2,635,046 acres developed[125]. Regulatory and Environmental Considerations - The company is subject to stringent environmental regulations that could materially affect production and operational costs[131]. - Colorado regulations require operators to phase in the use of recycled produced water for hydraulic fracturing, starting with a minimum of 2% in 2026 and potentially increasing to 35% by 2038[149]. - The company faces potential litigation risks from local governments alleging public nuisances related to climate change[144]. Workforce and Operations - The company had 122 full-time employees and 7 contractors as of December 31, 2025[161]. - The company has a hybrid work environment allowing employees to work outside the office on Mondays and Fridays[165]. - The principal office location is in Houston, Texas, consisting of 55,862 square feet of leased space[166]. Financial Instruments and Risk Management - The company utilizes commodity derivative financial instruments to mitigate the impact of fluctuations in oil and natural gas prices on revenues[390]. - The prices for oil, natural gas, and NGLs have been volatile, and this unpredictability is expected to continue in the future[390]. - A hypothetical $1 per barrel increase or decrease in the NYMEX WTI strip price would result in an increase or decrease of approximately $3.4 million in the fair value of oil derivative contracts[391]. - A hypothetical $0.10 per MMBtu increase or decrease in the NYMEX Henry Hub natural gas strip price would result in an increase or decrease of approximately $7.7 million in the fair value of natural gas derivative contracts[391]. - The credit risk associated with operators and customers is considered acceptable by the company[394]. Debt and Interest Rate Exposure - The company had $95.8 million weighted average outstanding borrowings under its Credit Facility, with a weighted-average interest rate of 7.03%[395]. - A 1% increase in the interest rate on the outstanding debt would result in an increase in interest expense of $1.0 million for the year ended December 31, 2025[395]. - The company does not currently have any interest rate hedges in place but may use derivative instruments to hedge exposure to variable interest rates in the future[395]. - The company evaluates the credit standing of counterparties to derivative contracts, including reviewing credit ratings and financial information[393]. - The inability of significant operators to meet obligations may adversely affect financial results, but the company believes the associated credit risk is manageable[394].

Core Viewpoint - Black Stone Minerals is expanding its drilling commitments and production capabilities, particularly in the Shelby Trough and Haynesville areas, with significant investments in seismic surveys and new well developments expected to enhance future production and revenue streams [3][4][6][16]. Group 1: Production and Development - Aethon has recently brought several new wells online in the Shelby Trough, producing approximately 25 MMcf to 30 MMcf per day, with five more wells expected to come online in the first quarter of 2026 [1]. - The partnership ended 2025 with a production rate of about 32,000 BOE per day and anticipates a material increase in production throughout 2026, supported by new well contributions and increased activity [5][7]. - Black Stone Minerals has signed development agreements with Revenant Energy and Katouris Energy, which will place around 500,000 gross acres into development and ramp up minimum drilling commitments to 37 gross wells per year by 2031 [2][6]. Group 2: Financial Performance and Distribution - The company reported a fourth-quarter mineral and royalty production average of 30,900 BOE per day, down 11% from the previous quarter, while total production averaged 32,100 BOE per day [12]. - The partnership has reiterated a quarterly distribution of $0.30 per unit, with a distributable cash flow of $66.8 million, representing a coverage ratio of 1.05x [17]. Group 3: Seismic Programs and Acquisitions - Black Stone is funding two 3D seismic surveys covering about 360,000 gross acres, with most costs expected in 2026 and completion targeted for early 2027 [4][13]. - The company has invested approximately $240 million in accretive mineral and royalty acquisitions across the Shelby Trough and Haynesville expansion area [11][14]. Group 4: Future Outlook - Management expressed optimism regarding growing natural gas demand linked to LNG and electric power generation, positioning the partnership to benefit from increased gas supply needs in the coming years [16].

Financial Data and Key Metrics Changes - In Q4, mineral and royalty production was 30,900 BOE per day, a decrease of 11% from the prior quarter [11] - Total production for the quarter was 32,100 BOE per day, completing the year at the high end of updated guidance [11] - Net income for Q4 was $72.2 million, with adjusted EBITDA at $76.7 million [13] - Distributable cash flow for the quarter was $66.8 million, representing 1.05x coverage for the period [13] Business Line Data and Key Metrics Changes - The company signed development agreements with Revenant Energy and Katouris Energy, placing approximately 500,000 gross acres into development [4] - Minimum drilling commitments ramp up to 37 gross wells per year by 2031, with a total of 50 gross wells expected over the same period [4][5] - Aethon brought several new wells online in the Shelby Trough, producing about 25 MMcf-30 MMcf a day, with additional wells expected in Q1 [4] Market Data and Key Metrics Changes - The company anticipates significant increases in natural gas production and distributions for unitholders over the coming years, driven by growing demand from LNG and electric power generation [14] - The outlook for natural gas is increasingly constructive over the next decade, supported by significant assets near Gulf Coast LNG facilities [14] Company Strategy and Development Direction - The company is focused on increasing production from existing assets and driving long-term value for unitholders through strategic acquisitions and development agreements [6][9] - A new opportunity is being built in the Haynesville expansion area, expected to add significant inventory and scale [5] - The company is strategically increasing G&A in 2026 to support increased activity levels [9] Management's Comments on Operating Environment and Future Outlook - Management views 2026 as a turning point with new and increased development in the Shelby Trough and Haynesville expansion areas [11] - The company remains confident in its ability to fund distributions and grow throughout the year based on minimum commitments and ongoing activity [32][33] - Management is optimistic about long-term growth due to substantial industry-leading inventory and advantageous proximity to key demand centers [9] Other Important Information - The partnership is conducting two substantial 3D seismic surveys covering about 360,000 gross acres, which is expected to enhance subsurface evaluation and accelerate development [12] - The proprietary nature of these surveys may provide opportunities to license the data to the industry, potentially generating additional revenue [12][37] Q&A Session Summary Question: Guidance for production levels throughout 2026 - Management indicated that production is expected to start at the end of 2025 levels and increase materially throughout 2026 due to new development agreements and high-interest projects [20][21] Question: Pipeline of potential new development agreements - Management welcomes both existing and new partners for development agreements and is focused on diversifying new developments [23] Question: Activity in the Permian and its priority - Management is excited about high-interest activity in the Permian and anticipates increased leasing and activity throughout 2026 and 2027 [28][29] Question: Funding the distribution through cash flow - Management expressed confidence in funding the $0.30 distribution through distributable cash flow without relying on liquidity, supported by strong hedges in place for natural gas [32][33] Question: Seismic expenses and their impact on adjusted EBITDA - Management confirmed that the seismic expenses are expected to be primarily incurred in 2026, with the majority of costs related to two specific shoots to be completed in early 2027 [35][36]

Financial Data and Key Metrics Changes - In the fourth quarter, mineral and royalty production was 30.9 thousand BOE per day, a decrease of 11% from the prior quarter, while total production for the quarter was 32.1 thousand BOE per day [11] - Net income for the fourth quarter was $72.2 million, with adjusted EBITDA at $76.7 million [13] - Distributable cash flow for the quarter was $66.8 million, representing 1.05 times coverage for the period [13] Business Line Data and Key Metrics Changes - The company achieved significant commercial milestones, including development agreements with Revenant Energy and Caturus Energy, placing approximately 500,000 gross acres into development [4] - Aethon brought several new wells online in the Shelby Trough at about 25-30 MMcf a day, with additional wells expected to come online in the first quarter [4][5] Market Data and Key Metrics Changes - The company anticipates significant increases in natural gas production and distributions for unitholders over the coming years, driven by growing demand from LNG and electric power generation [14] - The outlook for natural gas is increasingly constructive over the next decade, supported by the company's significant assets near Gulf Coast LNG facilities [15] Company Strategy and Development Direction - The company is focused on increasing production from existing assets and driving long-term value for unitholders, with a comprehensive commercial strategy that includes grassroots acquisitions and high-interest development agreements [9] - The company is strategically increasing G&A in 2026 to support the anticipated increase in activity [9] Management's Comments on Operating Environment and Future Outlook - Management expressed confidence that 2026 will be a turning point, with new and increased development in the Shelby Trough and Haynesville expansion areas [11] - The company is monitoring increasing activity levels in the Haynesville and commodity price dynamics as it looks towards 2026 production and distribution [11] Other Important Information - The partnership is conducting two substantial 3D seismic surveys covering about 360,000 gross acres, which are expected to enhance subsurface evaluation and accelerate development [12] - The company has invested about $240 million in its acquisition program since launching in 2023 [6] Q&A Session Summary Question: Guidance for the year and production cadence - Management indicated that production is expected to start at the end of 2025 levels and increase materially throughout 2026, primarily due to new development agreements and high-interest projects [20][21] Question: Pipeline of potential new development agreements - Management stated that they welcome both existing partners and newcomers for new developments, indicating a diverse approach to expanding their asset base [24] Question: Activity in the Permian and liquids guidance - Management highlighted excitement about high-interest activity in the Permian, with expectations for increased activity and volumes primarily in 2026 and 2027 [30][31] Question: Funding the distribution through cash flow - Management expressed confidence in funding the $0.30 distribution through distributable cash flow without relying on liquidity, supported by strong development commitments [34][35] Question: Seismic expenses and adjusted EBITDA - Management confirmed that the seismic expenses are expected to be primarily incurred in 2026, with the majority of costs related to the seismic shoots completed by early 2027 [37]

Core Insights - The company is expanding its operations in the Haynesville Basin, focusing on increasing production and long-term value for unitholders through new development agreements and acquisitions [1][3][5] Production and Development - Aethon has recently brought several new wells online in the Shelby Trough, producing approximately 25 to 30 million cubic feet per day, with more wells expected to come online in 2026 [2] - The company achieved significant commercial milestones in 2025, signing development agreements with Aethon Energy and Catena Resources, covering around 500,000 gross acres and committing to a minimum of 37 gross wells per year by 2031 [3][6] - The company ended 2025 with a production rate of about 32,000 barrels of oil equivalent (BOE) per day, with expectations for material growth throughout 2026 [6][9] Financial Performance - In the fourth quarter, the company reported a net income of $72.2 million and an adjusted EBITDA of $76.7 million, with a distribution of $0.30 per unit for the quarter [13] - The company’s royalty production was 30,900 BOE per day, reflecting an 11% decrease from the previous quarter, but it expects 2026 to be a turning point with increased activity and production [9][10] Strategic Initiatives - The company has invested approximately $240 million since 2023 to acquire mineral and royalty acreage in the Shelby Trough and Haynesville expansion area, aiming for significant growth and value for unitholders [5] - The company is conducting two substantial 3D seismic surveys covering about 360,000 gross acres to enhance subsurface evaluation and potentially generate additional revenue through licensing [11][12] Market Outlook - The company is optimistic about long-term growth due to its substantial inventory in the Shelby Trough and proximity to key demand centers, anticipating increased natural gas production and distributions to unitholders [7][14] - The outlook for natural gas is constructive over the next decade, driven by growing demand from LNG and electric power generation [13][14]

Financial Data and Key Metrics Changes - In Q4 2025, mineral and royalty production was 30.9 thousand BOE per day, a decrease of 11% from the prior quarter, while total production for the quarter was 32.1 thousand BOE per day [11] - Net income for the fourth quarter was $72.2 million, with adjusted EBITDA at $76.7 million [13] - Distributable cash flow for the quarter was $66.8 million, representing 1.05 times coverage for the period [13] Business Line Data and Key Metrics Changes - The company signed development agreements with Revenant Energy and Caturus Energy, placing approximately 500,000 gross acres into development, with commitments ramping up to 37 gross wells per year by 2031 [4] - Aethon brought several new wells online in the Shelby Trough at about 25-30 MMcf a day, with additional wells expected in Q1 2026 [4][5] Market Data and Key Metrics Changes - The company anticipates significant increases in natural gas production and distributions for unitholders over the coming years, driven by growing demand from LNG and electric power generation [14] - The outlook for natural gas is increasingly constructive over the next decade, supported by significant assets near Gulf Coast LNG facilities [14] Company Strategy and Development Direction - The company is focused on increasing production from existing assets and driving long-term value for unitholders through strategic acquisitions and development agreements [6][9] - A new opportunity is being built in the Haynesville expansion area, expected to add significant inventory and scale to current developments [5] Management's Comments on Operating Environment and Future Outlook - Management expressed optimism about the long-term growth for unitholders, citing substantial industry-leading inventory and advantageous proximity to key demand centers [9] - The company expects 2026 to be a turning point with new and increased development in the Shelby Trough and Haynesville expansion areas [11] Other Important Information - The partnership is conducting two substantial 3D seismic surveys covering about 360,000 gross acres, which are expected to enhance subsurface evaluation and accelerate development [12] - The company has updated the presentation of adjusted EBITDA and distributable cash flow to exclude seismic acquisition costs [13] Q&A Session Summary Question: Guidance for the year and production cadence - Management indicated that production is expected to start at the end of 2025 levels and increase materially throughout 2026 due to new development agreements and high-interest projects [19][20] Question: Pipeline of potential new development agreements - Management stated they welcome both existing and new partners for development agreements, emphasizing diversification in their approach [22][23] Question: Activity in the Permian and leasing outside Coterra - Management highlighted excitement about high-interest developments in the Permian, with increased activity expected in 2026 and 2027 [29][30] Question: Funding the distribution through distributable cash flow - Management expressed confidence in funding the $0.30 distribution through distributable cash flow without relying on liquidity, supported by strong hedges in place for natural gas [32][34] Question: Seismic expenses and adjusted EBITDA - Management confirmed that the seismic expenses are expected to be primarily incurred in 2026, with the majority of costs related to the seismic shoots completed by early 2027 [36][38]

Core Insights - Black Stone Minerals (BSM) reported a revenue of $118.7 million for the quarter ended December 2025, marking a year-over-year increase of 41.8% and an EPS of $0.31 compared to $0.18 a year ago [1] - The reported revenue exceeded the Zacks Consensus Estimate of $104 million, resulting in a surprise of +14.14%, while the EPS also surpassed expectations with a surprise of +16.24% against a consensus estimate of $0.27 [1] Financial Performance Metrics - BSM's production metrics included 32.1 million barrels of oil equivalent per day, slightly below the average estimate of 33.76 million barrels [4] - Natural gas production was reported at 13,118.00 MMcf, compared to the average estimate of 13,941.32 MMcf [4] - Oil and condensate production was 768.00 MBBL, lower than the average estimate of 779.52 MBBL [4] - Total production equivalents were 2,954.00 MBOE, compared to the average estimate of 3,103.24 MBOE [4] Revenue Breakdown - Revenue from lease bonuses and other income was $4.71 million, significantly exceeding the average estimate of $1.06 million, reflecting a year-over-year change of +137.6% [4] - Revenue from oil and condensate sales was $46.37 million, below the average estimate of $50.49 million, indicating a year-over-year decline of -22.7% [4] - Revenue from natural gas and natural gas liquids sales was $44.11 million, also below the average estimate of $48.5 million, but showing a year-over-year increase of +4.1% [4] Stock Performance - Over the past month, shares of Black Stone Minerals have returned +3.1%, outperforming the Zacks S&P 500 composite's +1.8% change [3] - The stock currently holds a Zacks Rank 3 (Hold), suggesting it may perform in line with the broader market in the near term [3]

Production and Reserves - Black Stone Minerals reported mineral and royalty production of 30.9 MBoe/d for Q4 2025, a decrease from 34.8 MBoe/d in Q4 2024[6]. - Full year 2025 production averaged 34.6 MBoe/d, with mineral and royalty volumes decreasing by 9% year-over-year to 33.3 MBoe/d[6][25]. - Estimated proved reserves at year-end 2025 were 54.8 MMBoe, a decrease of 4% from 57.4 MMBoe at year-end 2024[14]. - The total proved oil and gas reserves at December 31, 2025, were 54,845 MBoe, down from 57,380 MBoe at the end of 2024, indicating a decrease of 4.4%[44]. - The net proved developed reserves decreased from 54,283 MBoe at December 31, 2024, to 48,179 MBoe at December 31, 2025, a reduction of 11.2%[44]. Financial Performance - Net income for Q4 2025 was $72.2 million, down from $91.7 million in Q3 2025 and up from $46.3 million in Q4 2024[12]. - Total revenue for Q4 2025 was $118.703 million, an increase from $83.726 million in Q4 2024, representing a year-over-year growth of 41.8%[35]. - The Partnership's net income for Q4 2025 was $72.227 million, compared to $46.346 million in Q4 2024, marking a year-over-year increase of 55.7%[35]. - Adjusted EBITDA for Q4 2025 totaled $76.7 million, compared to $88.1 million in Q3 2025 and $90.2 million in Q4 2024[13]. - Adjusted EBITDA for the year ended December 31, 2025, was $337,353,000, down from $383,233,000 in 2024, reflecting a decrease of 12.0%[43]. - Distributable Cash Flow for the three months ended December 31, 2025, was $66,760,000, compared to $81,990,000 in 2024, a decline of 18.5%[43]. Sales and Pricing - Oil and condensate sales for the year ended December 31, 2025, were $209.361 million, down from $269.061 million in 2024, a decrease of 22.2%[35]. - Natural gas and natural gas liquids sales increased to $191.616 million for the year ended December 31, 2025, compared to $157.907 million in 2024, reflecting a growth of 21.4%[35]. - The average realized price for oil and condensate in Q4 2025 was $60.38 per barrel, down from $70.12 per barrel in Q4 2024, a decrease of 10.5%[37]. - The average realized price for natural gas in Q4 2025 was $3.36 per Mcf, up from $2.86 per Mcf in Q4 2024, an increase of 17.5%[37]. Cash Distribution and Expenses - Black Stone announced a cash distribution of $0.30 per common unit for Q4 2025, with a distribution coverage ratio of 1.05x[18]. - The total operating expenses for the year ended December 31, 2025, were $161.523 million, slightly up from $160.593 million in 2024[35]. - Cash interest expense for the year ended December 31, 2025, was $7,845,000, compared to $2,030,000 in 2024, showing a significant increase of 286.5%[43]. - Preferred unit distributions for the year ended December 31, 2025, totaled $29,466,000, consistent with the previous year[43]. Future Outlook - Black Stone expects 2026 mineral and royalty production to range from 32.5 to 34.5 MBoe/d, with total production projected between 33 and 36 MBoe/d[25]. - The company anticipates a significant production increase throughout 2026, primarily driven by activity in the Shelby Trough and Permian Basin[5][25]. - Development agreements with Revenant Energy and Caturus Energy will add a minimum of 8 wells in 2026, ramping to 37 wells by 2031[6][20][21]. - The Partnership's oil hedge position for 2026 includes 615 MBbl at a price of $64.39 per barrel for each quarter[28]. - The natural gas hedge position for 2026 includes 12,600 BBtu at a price of $3.73 per MMBtu for Q1 2026[29]. Conference Call - Black Stone Minerals will host a conference call on February 24, 2026, to discuss its results and outlook for 2026[30].