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Preliminary figures from the Texas Railroad Commission show the state produced 124,149,657 barrels of crude oil in November 2025

Texas reports November oil and gas output led by Midland area

Preliminary figures from the Texas Railroad Commission show the state produced 124,149,657 barrels of crude oil in November 2025 (about 4,138,321 barrels per day). Texas natural gas output for the month was reported at 1,002,396,104 Mcf (about 33,413,203 Mcf per day). The totals reflect volumes reported by operators from 157,813 oil wells and 83,966 gas wells, and they compare with updated November 2024 figures of 143,764,045 barrels of oil and 1,082,479,452 Mcf of natural gas.

The Midland area again led statewide oil production. Martin County topped the list at 20,755,579 barrels, followed by Midland County at 17,784,946 barrels, with additional high-producing counties including Upton, Loving, and Reeves. On the gas side, Webb County ranked first with 97,750,282 Mcf, followed by Reeves County (84,832,237 Mcf) and Midland County (77,756,512 Mcf). Reeves County also led Texas in condensate production at 6,338,309 barrels, with Loving County second at 4,288,680 barrels. For more context on Texas output trends and key drivers, see Texas leads the charge as America sets new oil and natural gas records and Permian gas wave sparks biggest pipeline buildout since the shale boom.

Source: Midland Reporter-Telegram
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Trump administration’s 5.5M-acre auction is one of several mandated over next few years for Alaska's federal lands and offshore waters.

First Federal oil & gas lease sale since 2019 set for Alaskan petroleum reserve

The Trump administration has scheduled an oil and gas lease sale covering about 5.5 million acres in the National Petroleum Reserve in Alaska (NPR-A), a 23-million-acre federal unit on Alaska’s western North Slope. The U.S. Bureau of Land Management (BLM) said bids will be opened on March 9, 2026, with full sale details to be released after the notice is published in the Federal Register.

BLM described the sale as the first NPR-A offering since 2019 and the first of five lease sales mandated over the next decade under the One Big Beautiful Bill Act passed last summer. The article notes that parts of the reserve are considered highly prospective, including areas associated with the Nanushuk formation, and that about 1.6 million acres in the NPR-A are already under lease. It also highlights ongoing and planned development in the region, including ConocoPhillips’ Willow project (expected startup in 2029, with peak production projected at 180,000 barrels per day) and nearby producing projects that began coming online over the last decade. For readers wanting background on how federal leasing works, see Leasing federal vs. private land for oil and gas exploration and Oil and gas lease basics.

Source: Alaska’s News Source
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Winter Storm Fern had its expected impact on energy production and markets that sparked a 110% rally in Henry Hub natural gas prices

Winter Storm Fern lifts Henry Hub gas prices as output dips in Texas

Winter Storm Fern tightened U.S. energy markets in late January, pushing Henry Hub natural gas prices up about 110% as cold-weather demand rose and upstream output eased. An analysis from the Texas Oil & Gas Association said Texas production declined roughly 7% to 10% while electricity demand increased about 40%. Over Jan. 22–26, ERCOT relied heavily on dispatchable generation—supplying up to 92% of output—with natural gas providing roughly 70% of total generation.

Rystad Energy estimated an initial natural gas decline of about 2 Bcf across several basins, followed by a sharper drop near 12 Bcf/d driven largely by the Permian and the broader Gulf Coast region. The firm also projected a January monthly-average oil impact of about 390,000 barrels per day from an onshore Lower 48 baseline of 11.378 million bpd, with output expected to recover as temperatures normalize. Rystad noted front-month Henry Hub moved from around $3.10 to $6.75 per MMBtu over the week beginning Jan. 19, reflecting both higher demand and reduced supply. TXOGA President Todd Staples said Texas gas production stayed near 28 Bcf/d and storage helped balance conditions, with withdrawals peaking near 12.8 Bcf/d. For mineral and royalty owners, price moves like these can influence payments (see how natural gas prices influence royalty payments) and may coincide with temporary operational pauses (see shut-in wells and royalties explained).

Source: Midland Reporter-Telegram
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Devon Energy and Coterra Energy are merging in an all-stock deal valued at $58 billion to create a new U.S. shale oil and gas heavyweight.

Devon and Coterra announce a $58 billion shale merger

Devon Energy and Coterra Energy have agreed to combine in an all-stock transaction that values the deal at roughly $58 billion. Under the terms announced on February 2, 2026, Coterra shareholders would receive 0.70 shares of Devon stock for each Coterra share, leaving Devon shareholders with about 54% of the combined company and Coterra shareholders with about 46%.

The companies say the merger would create a larger U.S. shale operator with a major footprint in the Permian Basin, including sizable adjacent positions in the Delaware Basin, alongside assets in other core U.S. producing regions. Leadership is expected to include Devon CEO Clay Gaspar as chief executive, with Coterra CEO Tom Jorden serving as non-executive chair. The companies also highlighted targeted cost and operating synergies, alongside a plan focused on scale, inventory depth, and shareholder returns—an approach that continues the broader consolidation trend across U.S. upstream producers.

If you want more background on oil & gas consolidation, see our explainer on industry consolidation and our overview of oil production in Texas.

Source: MSN
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Kazakhstan discussed energy cooperation with the US, highlighting its role as a major producer supplying about 2% of global oil.

U.S. and Kazakhstan discuss expanded energy cooperation

Kazakhstan’s energy ministry said it recently held talks with the U.S. Department of Energy and the U.S. Embassy in Kazakhstan focused on energy cooperation. According to the ministry, the discussions covered advancing Kazakhstan’s strategic priorities in the oil and gas sector. Kazakhstan is a major producer, accounting for about 2% of daily global oil supply.

The update comes as Kazakhstan’s output has been affected by operational disruptions in recent weeks, including a temporary 7–10 day outage at the Tengiz field. The ministry also referenced drone strikes that impacted tankers and onshore infrastructure tied to the Caspian Pipeline Consortium (CPC), a key export route that carries much of Kazakhstan’s crude for loading at Russia’s Novorossiysk port. U.S. companies, including Chevron and ExxonMobil, have significant stakes in Kazakhstan’s oilfields—an example of how cross-border ties can matter for supply reliability and market conditions (see Ranger’s overview of oil and gas price volatility drivers).

Separately, Kazakhstan’s ministry noted Washington has been working to deepen ties with Kazakhstan in recent months, adding broader context to the energy discussions.

Source: Oil & Gas 360
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
US Energy Secretary Chris Wright said that the world needs to more than double its oil production to bring more people out of energy poverty.

U.S. energy secretary urges major rise in global oil output

U.S. Energy Secretary Chris Wright said the world needs to more than double oil production, arguing that higher supply is critical to expanding access to reliable, affordable energy. Speaking at the World Economic Forum in Davos, Wright framed the issue as an “energy poverty” challenge and suggested global oil demand will remain durable for decades.

Wright also discussed how policy and regulatory frameworks can affect energy investment and cross-border energy trade, including requirements tied to emissions monitoring and reporting. He pointed to the scale of today’s market as context for his remarks, noting that global supply is already above 100 million barrels per day and that the U.S. has expanded production and export capacity in recent years. For additional context on U.S. output trends, see Ranger’s updates on recent EIA production forecasts and record onshore production on federal lands.

Source: Upstream
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
The surge in AI use and the data centers are set to boost power demand from data centers by 500% by 2040, UAE minister Al Jaber said.

Oil, gas seen supplying most power growth from data centers

Hydrocarbons are expected to provide roughly three-quarters of the projected rise in electricity demand from data centers as AI use expands and more facilities are built, according to comments from ADNOC CEO Sultan Al Jaber at Abu Dhabi Sustainability Week. He cited an estimate that power demand from data centers could increase by about 500% by 2040, and said oil and natural gas are likely to remain central to meeting that growth for decades.

Al Jaber also pointed to significantly higher infrastructure spending needs, saying the scale-up of AI and data center development is lifting global energy investment requirements to around $4 trillion per year, including funding for grids, data centers, and multiple energy sources. For additional context on how AI-related load is influencing the power market, see U.S Natural Gas Power Is Booming Thanks to AI and Texas approves $13.8B plan for Permian Basin grid.

Source: OilPrice.com
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
The US Geological Survey discovered new oil and gas reserves in the Permian Basin — enough to supply the US for 10 months.

USGS discovers new oil and gas reserves in the Permian Basin

The U.S. Geological Survey (USGS) says the Permian Basin may hold sizable additional oil and natural gas resources in the deeper Woodford and Barnett shale formations beneath West Texas and New Mexico. In a new assessment released Wednesday, the agency estimated about 1.6 billion barrels of technically recoverable oil and 28.3 trillion cubic feet of natural gas—volumes it said equate to roughly 10 weeks of U.S. oil use and about 10 months of U.S. gas consumption at current rates.

For producers, the assessment highlights why some Houston-based operators are increasingly looking beyond established drilling “landing zones” as they plan for longer-term supply. Researchers at the University of Texas Bureau of Economic Geology noted the Woodford and Barnett targets are deeper and hotter than many conventional Permian plays, which can raise costs and increase associated gas volumes. The Barnett also contains more clay, creating additional drilling hazards, and companies still need to pinpoint the most productive “sweet spots” before development can scale. For a practical overview of exploration steps mineral owners may hear about, see How to Find Oil on Your Land and Ranger’s Oil & Gas Royalties guide.

Source: Houston Chronicle
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
BLM leased 31 parcels totaling 20,399 acres in NM and OK for $326,811,240 in total receipts during a quarterly oil and gas lease sale.

BLM NM-OK lease sale raises nearly $327M in receipts

The U.S. Bureau of Land Management (BLM) reported that its latest quarterly oil and gas lease sale resulted in 31 parcels being leased across New Mexico and Oklahoma, covering 20,399 acres and generating $326,811,240 in total receipts. The agency said the proceeds—made up of lease bonus bids and rentals—are split between the federal government and the states where the parcels are located.

BLM said the sale set a new benchmark for a single-acre bid (more than $218,751) and ranked among the highest on record for total bonus bids (over $316 million). The agency also cited a top bid on an individual parcel of more than $70 million and an average bid exceeding $16,000 per acre. BLM noted the sale was held under the One Big Beautiful Bill Act, which set a minimum 12.5% royalty rate for new federal onshore production, replacing the 16.67% rate established under the Inflation Reduction Act—an update the agency said could improve project economics and support additional leasing activity. Leases are issued for 10 years and can continue as long as production remains in paying quantities; results are posted through BLM’s online leasing systems. For additional context, see Ranger’s overview of federal vs. private oil and gas leasing and how oil and gas royalties work.

Source: Bureau of Land Management
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
The Texas oil and natural gas industry employed 495,501 people in 2025, according to TXOGA's 2025 Energy and Economic Impact report.

TXOGA: Texas oil and gas employment topped 495,000 in 2025

The Texas oil and natural gas industry directly employed 495,501 people in 2025, according to the Texas Oil & Gas Association’s (TXOGA) newly released 2025 Energy and Economic Impact report. TXOGA said the largest job categories included oilfield support services, convenience-store gasoline retail, and pipeline-related construction. Other sizable segments included crude production and oilfield machinery and equipment manufacturing.

TXOGA also estimated that each direct industry job supports roughly two additional jobs elsewhere in the state, for about 1.4 million total jobs tied to the sector across the Texas economy. The report said oil and gas employers paid an average of $133,095 per job in 2025, and that combined state and local taxes plus state royalties attributed to the industry totaled $27.0 billion (about $74 million per day). For broader context on Texas output trends referenced in the report, see Texas production and export records, and for investors looking to understand cash-flow mechanics, how oil and gas royalties work.

Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.