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Occidental Petroleum, 1PointFive expect Phase1 of the STRATOS DAC plant in Texas' Permian basin to come online in this year’s 2nd quarter.

Stratos carbon capture plant targets second-quarter startup

Occidental Petroleum and its 1PointFive subsidiary said the first phase of the STRATOS direct air capture project in Ector County, Texas, is expected to begin operating in the second quarter of 2026. According to the company, the facility is in the final stage of startup, while commissioning for Phase 2 is also set to begin during the same quarter, with the broader operational ramp-up continuing through the rest of the year. Once fully online, STRATOS is designed to capture as much as 500,000 metric tons of carbon dioxide per year.

The update also outlined key progress already made at the site, including wet commissioning, testing of the CO2 compression system at design pressure, burner testing on the calciner, and the addition of potassium hydroxide for atmospheric CO2 capture. The project has also received Class VI permits for geologic sequestration, with plans to use three wells to store about 722,000 metric tons of CO2 annually in deep saline formations. For mineral owners and energy market watchers, the project adds to the broader conversation around how carbon capture initiatives impact oil and gas leasing and the potential CCUS revenue opportunities tied to emerging infrastructure in Texas and the Permian Basin.

Source: Oil & Gas Journal
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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.
Texas Rep. Brooks Landgraf says the Permian Basin is key to U.S. energy supply as Iran tensions impact global oil markets.

Permian output highlighted as strategic amid Iran tensions

Texas State Rep. Brooks Landgraf said the Permian Basin remains an important part of the U.S. energy picture as tensions involving Iran continue to affect global oil markets. The report, published by YourBasin, points to the market response following late-February military developments involving Iran and the resulting pressure on energy infrastructure and traffic through the Strait of Hormuz, one of the world’s most important oil transit routes.

Landgraf’s comments centered on the value of strong domestic production during periods when overseas supply routes face added pressure. For investors and mineral owners, the story underscores how major geopolitical events can increase attention on U.S. producing regions such as West Texas, where steady output and established infrastructure can play a larger role in supporting supply reliability and broader market stability. That backdrop also keeps interest elevated in assets tied to oil and gas development, including mineral rights and royalty opportunities in active producing areas.

Source: YourBasin

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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.
Oil and gas prices have surged as Iran continues to launch strikes across the Middle East in response to ongoing attacks by the US and Israel.

Two vessel incidents in the Strait of Hormuz lift oil shipping costs

Two commercial vessels were struck by projectiles near the Strait of Hormuz, a major shipping corridor between Iran and Oman that carries roughly a fifth of the world’s oil and significant LNG volumes. The incidents added to broader disruption in Gulf waters, with shipping data showing many crude and LNG carriers waiting offshore rather than transiting the area.

As risks increased, multiple marine insurers moved to cancel war-risk coverage for vessels operating in Iranian and nearby Gulf waters starting March 5, a step that can raise insurance and freight costs for cargoes moving from the Middle East. Tanker rates on key routes have climbed sharply this year, and oil prices rose as markets reacted to tighter near-term logistics and higher transport costs. For mineral and royalty owners, pricing and differentials can influence revenues over time, alongside market factors that shape payments (see how natural gas prices influence royalty payments and understanding oil and gas royalties).

Source: BBC News
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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.
Federal oil and gas policy tilts toward industry as regulatory relief continues and expands under Donald Trump.

Federal policy signals more U.S. leasing, permits, and LNG growth

A February 2026 World Oil outlook reviews federal actions since President Trump returned to office on Jan. 20, 2025, saying multiple agencies have prioritized faster approvals and expanded access for upstream development. The article cites Bureau of Land Management approval of 5,742 permits to drill from Jan. 20, 2025 to early Jan. 2026 (up 55% versus the comparable prior period) and 22 federal lease sales in 2025 covering about 328,000 acres across 10 states and generating more than $356 million. It also notes Interior used emergency procedures aimed at shortening permit timelines to 28 days, alongside expanded Arctic-related activity and offshore leasing plans.

On LNG, the piece says the Department of Energy ended the January 2024 pause on new export permits and approved export authorizations for five projects, including Port Arthur LNG Phase II and Venture Global’s CP2 (listed at up to 3.96 Bcfd). It adds that DOE is streamlining grid connections tied to rising data-center power demand and expects U.S. natural gas exports in 2026 to be 4 Bcfd higher than in 2024 (a 33% increase). For mineral owners tracking activity drivers, context on oil and gas leasing regulations and what typically prompts operators to move forward can help frame how these policy signals may translate to local interest (see how drilling decisions take shape).

Source: World Oil
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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.
United States Supreme Court voids some Trump tariffs, but steel and aluminum levies under Section 232 stand.

Supreme Court tariff ruling may ease oilfield input costs over time

The U.S. Supreme Court ruled 6–3 that President Donald Trump exceeded his authority when he imposed certain tariffs under the 1977 International Emergency Economic Powers Act, which invalidated many of those duties. However, tariffs affecting key oilfield inputs—including steel, aluminum, and copper—remain in place because they were issued under Section 232 of the 1962 Trade Expansion Act, according to the Midland Reporter-Telegram.

Claudio Galimberti, chief economist at Rystad Energy, said the decision limits the government’s ability to target individual countries but does not remove the broader tariff framework, citing a continuing global tariff structure that could rise from 10% to 15%. Economist Ray Perryman told the Reporter-Telegram that while tariffs may be harder to maintain, other legal tools could be used, and he expects that any gradual reduction in tariff pressure could lower steel and equipment costs and support broader consumer and business activity—factors that can matter for energy demand and project economics. The American Petroleum Institute’s Aaron Padilla emphasized the value of predictable trade policy for market reliability.

Related Ranger coverage: Trump threatens tariffs if EU doesn’t buy more US oil and gas and Texas leads the charge as America sets new oil and natural gas records.

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.
The US EIA projects US marketed natural gas production will rise about 2% to average 120.8 Bcf/d in 2026, hitting 122.3 bcf/d record in 2027.

EIA sees US natural gas output hitting records in 2026–2027

The U.S. Energy Information Administration (EIA) projects U.S. marketed natural gas production will rise about 2% to average 120.8 Bcf/d in 2026 and then increase to a record 122.3 Bcf/d in 2027. The agency expects roughly 69% of the next two years’ output to come from three core regions: Appalachia, Haynesville, and the Permian.

EIA attributes much of the growth to higher forecast prices supporting activity in Haynesville, where production is expected to increase by about 1.2 Bcf/d in 2026 and 1.6 Bcf/d in 2027. The outlook also notes the region’s proximity to Gulf Coast LNG export terminals and major industrial demand. In the Permian, EIA expects gas volumes to grow mainly as associated gas from oil production, aided by rising gas-to-oil ratios, with the basin contributing 1.4 Bcf/d of growth in 2026 and 0.6 Bcf/d in 2027. Appalachia is projected to post modest gains as additional takeaway capacity supports incremental increases after recent constraints—context that mineral owners often evaluate alongside average natural gas well production benchmarks and basin-specific dynamics like Permian associated gas trends.

Source: Gas Compression Magazine
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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-controlled Venezuelan oil sales could bring in about $5B more revenue over the next few months, said US Energy Secretary Chris Wright.

U.S.-managed Venezuelan oil sales projected to bring $5 billion

Oil sales from Venezuela that have been administered under a U.S.-controlled framework for about five weeks are expected to generate roughly $5 billion in additional revenue over the next few months, according to U.S. Energy Secretary Chris Wright in an interview with NBC News. Wright said sales to date have topped $1 billion and that short-term agreements are in place for further deliveries. He made the comments during a trip to Venezuela that included meetings with interim President Delcy Rodríguez.

Wright said proceeds from the crude sales are routed through a U.S. Treasury-controlled account and ultimately remitted back to Venezuela, with commodity traders Vitol and Trafigura involved in handling the transactions. The report also noted that the U.S. has already transferred $500 million in sale proceeds to Caracas following a deal reached in January. Wright added that restoring Venezuela’s oil sector would require substantial investment, and he signaled expectations for higher oil, natural gas, and power production, while noting that recent legal changes are a constructive step but may still fall short of attracting large-scale capital. For related market context, see Ranger’s coverage of U.S.-Venezuela tensions and supply uncertainty.

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.
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.