Tag Archive for: oilandgas

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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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.
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.
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.
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.
Oil rises as geopolitical tensions continue. Brent crude is up 1% to $60.89 a barrel, while WTI rises 1.15% to $57.39 a barrel.

Oil prices rise as U.S.-Venezuela tensions add supply uncertainty

Oil prices moved higher in early trading as markets tracked escalating tensions between the United States and Venezuela and what that could mean for near-term crude supply flows. Brent crude rose about 1% to around $60.89 a barrel, while U.S. West Texas Intermediate gained roughly 1.15% to about $57.39 a barrel.

The latest uptick comes as Washington has stepped up pressure on Venezuelan oil shipments, a dynamic that traders have been watching for potential effects on exports. Recent U.S. actions aimed at sanctioned Venezuelan tankers have raised the possibility of disrupted cargo movements, with roughly 590,000 barrels a day of exports viewed as exposed in a tighter enforcement scenario. For investors, these developments add a geopolitical variable to pricing alongside broader market fundamentals, and can influence the revenue outlook tied to benchmarks that feed into oil and gas royalties over time.

Source: The Wall Street Journal
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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.