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88 Energy acquires Alaska North Slope leases

Captivate Energy Alaska Inc., a wholly owned subsidiary of 88 Energy Ltd., was the successful bidder for acreage east and west of Project Leonis in Alaska’s North Slope Areawide 2025W Oil and Gas Lease Sale. Fourteen new leases cover about 34,560 acres across South Prudhoe and Kad River East, the comapny said in a release Nov. 20. In South Prudhoe, seven leases cover Ivishak structural closures immediately south of the Prudhoe Bay Unit. The Ivishak formation offers high-quality, clean sandstone reservoir across the entire prospective area, with predicted 20% porosity, 50-100 mD permeability, and high charge potential across the newly acquired acreage.   3D seismic data, regional well control, and petrophysical analysis has delineated a suite of low-risk Ivishak formation prospects to be the first drill-ready targets for future exploration and appraisal. Further technical work, including seismic reprocessing, will be undertaken in 2026 to refine volumetrics and support prospective resource certification ahead of future farm-out and drilling decisions. Farm-out and planning are underway to drill a multi-zone exploration well targeting the Ivishak reservoir and shallower Canning and USB reservoirs. In Kad River East, seven leases east of the Trans Alaska Pipeline System (TAPS) exist in an under-explored region. A 3D seismic survey is scheduled for licensing and reprocessing in 2026. This data, combined with historical well data showing an active multi-reservoir petroleum system across the area, will help identify multiple targets. An early dual-hub development concept for the South Prudhoe and Leonis area will evaluate a low capital expenditure tie-back to Prudhoe Bay and Kuparuk River Units or a direct hot-tap connection into TAPS.

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ExxonMobil takes 40% share in Enterprise Products’ Bahia NGL pipeline, plans expansion

ExxonMobil Corp. will acquire from Enterprise Products Partners LP, Houston, a 40% undivided joint interest (UJI) in Enterprise’s Bahia natural gas liquids (NGL) pipeline with investment aimed at increasing throughput by 400,000 b/d.   ExxonMobil will contribute its proportionate share of Bahia project costs to date, or about $650 million, according to an SEC filing.   The 550-mile Bahia pipeline, which has started commissioning activities and will begin commercial operations immediately thereafter, will have an initial capacity to transport 600,000 b/d of NGLs from the Midland and Delaware basins of West Texas to Enterprise’s Mont Belvieu fractionation complex, Enterprise said in a release Nov. 20. The companies’ plan to increase Bahia’s capacity to 1 million b/d includes adding incremental pumping capacity and constructing a 92-mile extension to ExxonMobil’s Cowboy natural gas processing plant in Eddy County, NM. ExxonMobil will own a 70% UJI in this extension. The extension will also connect to multiple Enterprise-owned processing plants in the Delaware basin. The expansion and extension are expected to be completed in fourth-quarter 2027. ExxonMobil’s interest will be referred to as the Cowboy Connector. Enterprise will operate the combined system. Growing Permian basin production ExxonMobil, in a separate statement Nov. 20, said the investment will help connect its growing production in the Permian basin to US Gulf Coast refining and chemical plants and enable access to export logistics to serve markets around the world. In its third-quarter report released late last month, ExxonMobil said it set a Permian production record of nearly 1.7 MMboe/d, while expanding its use of low-cost refinery coke as a proppant that penetrates deeper into fracs, improving well recoveries by up to 20%. Noting the growth in Permian output, A.J. “Jim” Teague, co-chief executive officer of Enterprise’s general partner, pointed to the increasing ratio of natural gas and NGL production

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Continental Resources to enter Argentina’s Vaca Muerta shale as operator

Continental Resources Inc., Oklahoma City, is marking its first operational role outside the US with an agreement to acquire a 90% operating stake in the Los Toldos II Oeste block in Argentina’s Vaca Muerta. The privately held company has started the regulatory process to register its local subsidiary, Continental Resources Argentina SAU, as part of its entry into Argentina. The deal, made with Pluspetrol, was disclosed through a filing with Argentina’s National Securities Commission (CNV) and local media. Gas y Petróleo del Neuquén (GyP), the provincial energy company, would hold the remaining 10%.  The block was previously operated by Pluspetrol, which had acquired Los Toldos through its deal to acquire ExxonMobil’s Argentine assets.  While financial terms were not disclosed, Pluspetrol confirmed that the transaction remains subject to customary conditions precedent, including regulatory approval from the province of Neuquén, which oversees upstream concession rights. Continental’s arrival comes as President Javier Milei’s administration seeks to attract US operators to accelerate unconventional development. Argentina’s Economy Minister Luis Caputo praised the deal, calling it “a concrete signal of confidence” in the country’s macroeconomic stabilization efforts and its strategy to scale up Vaca Muerta. High-potential, early-stage block Los Toldos II Oeste lies within Vaca Muerta’s liquids-rich fairway in the northwestern sector of the basin. The block spans 77.7 sq km and sits in an oil window with attractive thickness, pressure, and rock quality, though still far from the industrial development levels of core blocks. To date, the block has seen only three wells drilled, underscoring its early-stage nature and contrasting with mature areas such as Loma Campana (YPF–Chevron) and Bajada del Palo (Vista), where activity follows full factory-drilling models. Analysts expect Continental Resources to deploy elements of its US playbook: extended-reach horizontals. high-intensity frac designs. pad drilling. sequential development strategies aimed at lowering costs and stabilizing productivity

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EIA: Alaska oil output to grow 13% in 2025

After decades of steady decline, Alaska’s oil output is set for a significant rebound. EIA projects a 13% increase—about 55,000 b/d—in 2026, marking the state’s largest year-over-year growth since the 1980s. The turnaround is led by two major developments on the North Slope. ConocoPhillips’ Nuna project, which began producing in December 2024, has shown steady growth. The field produced 7,000 b/d in August 2025 and is expected to reach 20,000 b/d at its peak, helping offset declines in legacy fields. A larger boost is expected from Pikka Phase 1, jointly owned by Santos and Repsol. The project is scheduled to begin production in first-quarter 2026 and reach peak production of 80,000 b/d by mid-2026, nearly 20% of total Alaska oil production in 2025. EIA noted that wells from these new projects outperform most existing wells in the state. Recent production records from the Alaska Oil and Gas Conservation Commission show that new wells produce about 480 boe/d, whereas 78% of Alaskan wells produced less than 400 boe/d in 2023. The agency said its upgraded 2026 outlook reflects Santos’s accelerated ramp-up to peak production for the Pikka Phase 1 project and recent well tests demonstrating high productivity.

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BW Energy confirms liquid hydrocarbons in Kudu area offshore Namibia

BW Energy has confirmed the presence of liquid hydrocarbons in the Kudu license area in Orange basin offshore Namibia. Results come following completed drilling operations on the Kharas-1 appraisal well in the Kudu license area, the company said in a release Nov. 19. The Kharas prospect, on the northwest portion of the Kudu formation, was sanctioned as part of BW Energy’s broader plan to identify upside targets in the 4,567-sq license area (PPL003) following seismic acquisition in 2023. Kharas-1 achieved its technical objective of testing multiple targets within a single penetration, said Carl Arnet, chief executive officer, and the results “confirm, for the first time, the presence of liquid hydrocarbons” within the block, contributing to the company’s understanding of the broader petroleum system. Arnet said the reservoir complexity requires additional appraisal to assess its potential and that a forward program “will focus on further high value targets based on the presence of liquid hydrocarbons, as well as gas and the learnings from Kharas-1A.” The well reached a total depth of 5,100 m and intersected multiple reservoir intervals. Several shallow turbidite reservoirs with dry-gas shows were encountered, and reservoir properties from these and the acquired whole core are now being evaluated, the company said. In the deeper section of the well, hydrocarbons were encountered in a fractured volcaniclastic reservoir, which the company said confirms a working petroleum system with condensate and/or light oil. Further analysis is ongoing to determine the extent of the system and to characterize reservoir properties and appraisal options. The well will now be plugged. Kudu gas field was discovered in 1974 about 130 km off the southwest coast of Namibia in in water depth of 170 m. It is delineated by seven subsequent wells.  

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Shell UK farms out 50% stake in West of Shetland Tobermory gas discovery to Ithaca Energy

Shell UK agreed to farm out 50% non-working interest in two West of Shetland basin licenses to UK oil and gas operator Ithaca Energy plc. Financial terms were not disclosed. The UK North Sea licenses, P2629 and P2630, contain the Tobermory gas discovery, Ithaca Energy said in a release Nov. 19.  Ithaca Energy, as part of its third-quarter report also released Nov. 19, listed estimated gross 2C resource at Tobermory of 60-65 MMboe as of Dec. 31, 2024.   Following completion of the farm-in, Shell UK will continue to hold a 50% stake in the Tobermory discovery and act as license operator. The farm-out builds on the companies’ partnership in the UK Continental Shelf and fits into Ithaca Energy’s broader strategy to expand investment in the West of Shetland area. Shell UK and Ithaca Energy are existing 50-50 partners in the Tornado discovery.  As part of its third-quarter release, Ithaca said the Tornado project is progressing toward a financial investment decision (FID) with tendering and advancement of the Environmental Statement. Tornado’s estimated gross 2C resource is estimated by Ithaca at 67 MMboe.  In the release announcing the deal, Yaniv Friedman, executive chairman, Ithaca Energy, said the West of Shetland “represents a key basin for the Group’s long-term growth, with the ongoing development of the Rosebank field and the continued progression of the Cambo and Tornado discoveries towards final investment decision.” 

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88 Energy acquires Alaska North Slope leases

Captivate Energy Alaska Inc., a wholly owned subsidiary of 88 Energy Ltd., was the successful bidder for acreage east and west of Project Leonis in Alaska’s North Slope Areawide 2025W Oil and Gas Lease Sale. Fourteen new leases cover about 34,560 acres across South Prudhoe and Kad River East, the comapny said in a release Nov. 20. In South Prudhoe, seven leases cover Ivishak structural closures immediately south of the Prudhoe Bay Unit. The Ivishak formation offers high-quality, clean sandstone reservoir across the entire prospective area, with predicted 20% porosity, 50-100 mD permeability, and high charge potential across the newly acquired acreage.   3D seismic data, regional well control, and petrophysical analysis has delineated a suite of low-risk Ivishak formation prospects to be the first drill-ready targets for future exploration and appraisal. Further technical work, including seismic reprocessing, will be undertaken in 2026 to refine volumetrics and support prospective resource certification ahead of future farm-out and drilling decisions. Farm-out and planning are underway to drill a multi-zone exploration well targeting the Ivishak reservoir and shallower Canning and USB reservoirs. In Kad River East, seven leases east of the Trans Alaska Pipeline System (TAPS) exist in an under-explored region. A 3D seismic survey is scheduled for licensing and reprocessing in 2026. This data, combined with historical well data showing an active multi-reservoir petroleum system across the area, will help identify multiple targets. An early dual-hub development concept for the South Prudhoe and Leonis area will evaluate a low capital expenditure tie-back to Prudhoe Bay and Kuparuk River Units or a direct hot-tap connection into TAPS.

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ExxonMobil takes 40% share in Enterprise Products’ Bahia NGL pipeline, plans expansion

ExxonMobil Corp. will acquire from Enterprise Products Partners LP, Houston, a 40% undivided joint interest (UJI) in Enterprise’s Bahia natural gas liquids (NGL) pipeline with investment aimed at increasing throughput by 400,000 b/d.   ExxonMobil will contribute its proportionate share of Bahia project costs to date, or about $650 million, according to an SEC filing.   The 550-mile Bahia pipeline, which has started commissioning activities and will begin commercial operations immediately thereafter, will have an initial capacity to transport 600,000 b/d of NGLs from the Midland and Delaware basins of West Texas to Enterprise’s Mont Belvieu fractionation complex, Enterprise said in a release Nov. 20. The companies’ plan to increase Bahia’s capacity to 1 million b/d includes adding incremental pumping capacity and constructing a 92-mile extension to ExxonMobil’s Cowboy natural gas processing plant in Eddy County, NM. ExxonMobil will own a 70% UJI in this extension. The extension will also connect to multiple Enterprise-owned processing plants in the Delaware basin. The expansion and extension are expected to be completed in fourth-quarter 2027. ExxonMobil’s interest will be referred to as the Cowboy Connector. Enterprise will operate the combined system. Growing Permian basin production ExxonMobil, in a separate statement Nov. 20, said the investment will help connect its growing production in the Permian basin to US Gulf Coast refining and chemical plants and enable access to export logistics to serve markets around the world. In its third-quarter report released late last month, ExxonMobil said it set a Permian production record of nearly 1.7 MMboe/d, while expanding its use of low-cost refinery coke as a proppant that penetrates deeper into fracs, improving well recoveries by up to 20%. Noting the growth in Permian output, A.J. “Jim” Teague, co-chief executive officer of Enterprise’s general partner, pointed to the increasing ratio of natural gas and NGL production

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Continental Resources to enter Argentina’s Vaca Muerta shale as operator

Continental Resources Inc., Oklahoma City, is marking its first operational role outside the US with an agreement to acquire a 90% operating stake in the Los Toldos II Oeste block in Argentina’s Vaca Muerta. The privately held company has started the regulatory process to register its local subsidiary, Continental Resources Argentina SAU, as part of its entry into Argentina. The deal, made with Pluspetrol, was disclosed through a filing with Argentina’s National Securities Commission (CNV) and local media. Gas y Petróleo del Neuquén (GyP), the provincial energy company, would hold the remaining 10%.  The block was previously operated by Pluspetrol, which had acquired Los Toldos through its deal to acquire ExxonMobil’s Argentine assets.  While financial terms were not disclosed, Pluspetrol confirmed that the transaction remains subject to customary conditions precedent, including regulatory approval from the province of Neuquén, which oversees upstream concession rights. Continental’s arrival comes as President Javier Milei’s administration seeks to attract US operators to accelerate unconventional development. Argentina’s Economy Minister Luis Caputo praised the deal, calling it “a concrete signal of confidence” in the country’s macroeconomic stabilization efforts and its strategy to scale up Vaca Muerta. High-potential, early-stage block Los Toldos II Oeste lies within Vaca Muerta’s liquids-rich fairway in the northwestern sector of the basin. The block spans 77.7 sq km and sits in an oil window with attractive thickness, pressure, and rock quality, though still far from the industrial development levels of core blocks. To date, the block has seen only three wells drilled, underscoring its early-stage nature and contrasting with mature areas such as Loma Campana (YPF–Chevron) and Bajada del Palo (Vista), where activity follows full factory-drilling models. Analysts expect Continental Resources to deploy elements of its US playbook: extended-reach horizontals. high-intensity frac designs. pad drilling. sequential development strategies aimed at lowering costs and stabilizing productivity

Read More »

EIA: Alaska oil output to grow 13% in 2025

After decades of steady decline, Alaska’s oil output is set for a significant rebound. EIA projects a 13% increase—about 55,000 b/d—in 2026, marking the state’s largest year-over-year growth since the 1980s. The turnaround is led by two major developments on the North Slope. ConocoPhillips’ Nuna project, which began producing in December 2024, has shown steady growth. The field produced 7,000 b/d in August 2025 and is expected to reach 20,000 b/d at its peak, helping offset declines in legacy fields. A larger boost is expected from Pikka Phase 1, jointly owned by Santos and Repsol. The project is scheduled to begin production in first-quarter 2026 and reach peak production of 80,000 b/d by mid-2026, nearly 20% of total Alaska oil production in 2025. EIA noted that wells from these new projects outperform most existing wells in the state. Recent production records from the Alaska Oil and Gas Conservation Commission show that new wells produce about 480 boe/d, whereas 78% of Alaskan wells produced less than 400 boe/d in 2023. The agency said its upgraded 2026 outlook reflects Santos’s accelerated ramp-up to peak production for the Pikka Phase 1 project and recent well tests demonstrating high productivity.

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BW Energy confirms liquid hydrocarbons in Kudu area offshore Namibia

BW Energy has confirmed the presence of liquid hydrocarbons in the Kudu license area in Orange basin offshore Namibia. Results come following completed drilling operations on the Kharas-1 appraisal well in the Kudu license area, the company said in a release Nov. 19. The Kharas prospect, on the northwest portion of the Kudu formation, was sanctioned as part of BW Energy’s broader plan to identify upside targets in the 4,567-sq license area (PPL003) following seismic acquisition in 2023. Kharas-1 achieved its technical objective of testing multiple targets within a single penetration, said Carl Arnet, chief executive officer, and the results “confirm, for the first time, the presence of liquid hydrocarbons” within the block, contributing to the company’s understanding of the broader petroleum system. Arnet said the reservoir complexity requires additional appraisal to assess its potential and that a forward program “will focus on further high value targets based on the presence of liquid hydrocarbons, as well as gas and the learnings from Kharas-1A.” The well reached a total depth of 5,100 m and intersected multiple reservoir intervals. Several shallow turbidite reservoirs with dry-gas shows were encountered, and reservoir properties from these and the acquired whole core are now being evaluated, the company said. In the deeper section of the well, hydrocarbons were encountered in a fractured volcaniclastic reservoir, which the company said confirms a working petroleum system with condensate and/or light oil. Further analysis is ongoing to determine the extent of the system and to characterize reservoir properties and appraisal options. The well will now be plugged. Kudu gas field was discovered in 1974 about 130 km off the southwest coast of Namibia in in water depth of 170 m. It is delineated by seven subsequent wells.  

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Shell UK farms out 50% stake in West of Shetland Tobermory gas discovery to Ithaca Energy

Shell UK agreed to farm out 50% non-working interest in two West of Shetland basin licenses to UK oil and gas operator Ithaca Energy plc. Financial terms were not disclosed. The UK North Sea licenses, P2629 and P2630, contain the Tobermory gas discovery, Ithaca Energy said in a release Nov. 19.  Ithaca Energy, as part of its third-quarter report also released Nov. 19, listed estimated gross 2C resource at Tobermory of 60-65 MMboe as of Dec. 31, 2024.   Following completion of the farm-in, Shell UK will continue to hold a 50% stake in the Tobermory discovery and act as license operator. The farm-out builds on the companies’ partnership in the UK Continental Shelf and fits into Ithaca Energy’s broader strategy to expand investment in the West of Shetland area. Shell UK and Ithaca Energy are existing 50-50 partners in the Tornado discovery.  As part of its third-quarter release, Ithaca said the Tornado project is progressing toward a financial investment decision (FID) with tendering and advancement of the Environmental Statement. Tornado’s estimated gross 2C resource is estimated by Ithaca at 67 MMboe.  In the release announcing the deal, Yaniv Friedman, executive chairman, Ithaca Energy, said the West of Shetland “represents a key basin for the Group’s long-term growth, with the ongoing development of the Rosebank field and the continued progression of the Cambo and Tornado discoveries towards final investment decision.” 

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Expand sees value in keeping natural gas pipeline stake

Expand Energy Corp., Oklahoma City, is in “no rush” to sell its stake in the New Generation Gas Gathering (NG3) pipeline that entered service last month, the company’s chief operating officer told an investment bank conference on Nov. 20. The 255-mile NG3 project was developed by Momentum Sustainable Ventures LLC and was placed into service Oct. 1 after starting commissioning work in late August. It is moving natural gas from the Haynesville basin to the Gulf Coast, ending in Gillis, La., and has a capacity of 1.7-bcfd. Expand—then still Chesapeake Energy before its merger with Southwestern Energy—signed onto the project in late 2022 and has a stake that executives valued at $317 million as of Sept. 30. Asked at the Stephens Annual Investment Conference being held in Nashville if Expand might look to cash in on that commitment now that the NG3 pipeline is up and running, Josh Viets said “that option is there” but also made it clear he and other executives see upside to their investment. “If somebody showed up at the door with something that we just couldn’t pass up, we’re going to listen,” Viets said. “But financially, the balance sheet is in a great spot and we feel no pressure to look at an opportunity to monetize that right now. We love the investment. We think there’s a ton of value with it and we only expect that value to increase over time.”

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Vista expands Vaca Muerta base with $4.5-billion plan to reach 180,000 boe/d by 2028

Vista Energy plans to invest more than $4.5 billion in Vaca Muerta operations in Argentina between 2026 and 2028 with a goal to increase production by 60% to 180,000 boe/d by 2028 and up to 200,000 boe/d by 2030. In third-quarter 2025, Vista averaged 126,000 boe/d, including 110,000 b/d of oil. The 74% year-on-year increase was driven by growth in the operated blocks Bajada del Palo Oeste, Bajada del Palo Este, and Aguada Federal, together with a 50% stake in La Amarga Chica. Combined, these assets total 1,473 wells in inventory, with 335 currently producing, across 228,000 net acres under concession through 2054. The investment plan is supported by existing infrastructure: 144,000 b/d of evacuation capacity secured through contracts on Oldelval Duplicar, Vaca Muerta Norte, and Vaca Muerta Sur pipelines, and 178,000 b/d of crude treatment capacity, including 75,000 b/d at La Amarga Chica. In the third quarter, Vista spent $350.8 million. Of that, $216 million was spent on drilling and completions of nine wells drilled and sixteen completed in Vaca Muerta (typical lateral of 2,800 m, 47 stages); $105.4 million in La Amarga Chica (non-operated); $13.6 million in surface infrastructure; and $15.8 million in geoscience and IT studies. Vista expects annual free cash flow between 2026 and 2028 of $1.5 billion, assuming Brent oil prices of $65-70/bbl—enough to self-finance its capital program. Export revenues of $8 billion are expected over the next 3 years. During a presentation in Neuquén, Vista’s chief executive officer, Miguel Galuccio, said the company’s next phase is built on a more stable macroeconomic environment and renewed access to international capital markets. “Stabilizing the economy and gaining access to capital markets is the best thing the country could have done for Vaca Muerta,” he said. There is still room to improve regulatory and fiscal components that

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North American weekly rig count rises as counts in Canada, US both increase

North American drilling activity posted an increase for the week ended Nov. 21, with 749 total rotary rigs working in the US and Canada this week, Baker Hughes officials reported Friday. Oil drove the gain in Canada, with 128 rigs drilling for oil this week, 4 more than the previous week. Three additional rigs were gas-directed this week, increasing the count to 67 from the prior week. Canada’s total rig count of 195 is 6 fewer than this time last year. The US rig count is up 5 from the previous week to 554 rigs working. The count is down 29 from the same period in 2024. The number of rigs drilling on land increased by 6 units to 533 rigs working. That count is down 35 from the same period a year ago. One fewer rig was drilling in inland waters, leaving 2 working. The offshore rig count is unchanged at 19. In the US, gas-directed rigs increased by 2 to 127, up 28 from the same time last year. The number of oil-directed rigs also increased by 2, with a total of 419 rigs working this week. That number is 60 fewer than the 479 rigs drilling for oil in the US and its waters this time last year. Wyoming gained 3 rigs to end the week with 15 working. New Mexico, Oklahoma, and Pennsylvania each added a rig to end the week with respective counts of 106, 42, and 18. Louisiana, North Dakota, and Alaska each dropped a rig to end the week with 43, 27, and 9 rigs running, respectively.  

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SM Energy, Civitas set $1-billion post-merger divestiture target

The leaders of SM Energy Co. and Civitas Resources Inc. plan to sell at least $1 billion worth of assets in the year after joining forces. Following up on the merger announcement from earlier this month—under which SM Energy will pay about $2.7 billion in stock for Civitas to create a company with operations in four US basins—executives also added details about where they expect to generate cost savings by combining the two Denver-based companies.  In setting the $1-billion divestiture target, Herb Vogel, SM Energy’s chief executive officer, Beth McDonald—now president and chief operating officer of SM and tabbed to be the combined company’s leader come spring—and others pointed to a recent “robust” market for oil-and-gas deals. Among the transactions they cite as benchmarks are ConocoPhillips’ $1.3-billion sale of assets in the Anadarko basin, the $2.3-billion sale by Canada’s Baytex of its US foothold in the Eagle Ford, and Civitas’ own $435 million divestiture of Denver-Julesburg basin assets its leaders considered non-core. Based on the valuations of those deals, the $1 billion being eyed by the SM-Civitas team suggests the company will look to sell about 30,000 boe/d of production. The combined company’s output in the third quarter would have been 550,000 boe/d. On the synergies front, executives broke down their previously announced target of $200-$300 million annually into the following buckets: Drilling and completion as well as operational: $100-150 million, which amounts to about 2.5% of the companies’ combined spending. Administrative: $70-95 million from streamlining corporate teams and integrating offices and technology systems. Cost of capital: $30-55 million from paying down and/or refinancing debt. Set to join McDonald in the C-suite once the deal is completed, which is expected early next year, are the following SM veterans: Wade Pursell, SM’s chief financial officer since September 2008. Blake McKenna, who today oversees

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DNO enters deal with Orlen, aims to strengthen North Sea portfolio

Norwegian oil and gas operator DNO ASA has entered additional deals to rework its North Sea portfolio. Through all-cash transactions, the values for which were not disclosed, Orlen Upstream Norway AS agreed to acquire DNO’s 7.604% stake in the Ekofisk Previously Produced Fields (PPF) project in license PL018B and PL018F. From Orlen, DNO will acquire a 20% interest in license PL1135, which contains the Cassio prospect, as well as a 0.8272% interest in Verdande field. DNO will retain its 7.604% in PL018 containing producing fields Ekofisk, Eldfisk, and Embla as well as a share in the Tor Unit. Upon closing of the deal, subject to government approvals, the deals would bring DNO’s total interest in the Verdande Unit containing five licenses to 14.8251%, including 3.5% from the recently announced asset swap with Aker BP. Verdande, in the Norne area, is currently in advanced development and scheduled to start production later this year. Cassio lies directly north of DNO-operated PL1086 (50%), which includes the Othello discovery. An exploration well on Cassio is expected in late 2026. DNO executive chairman Bijan Mossavar-Rahmani said the company has chosen to deploy capital expenditure “in ways that play to our strengths, namely exploration and rapid-fire development of our existing discoveries.”

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IEA: Global gas demand growth slowed in 2025 but set to rebound in 2026

Global natural gas demand growth has weakened significantly in the first 3 quarters of 2025 following a relatively strong rebound in 2024, weighed down by higher prices, tighter supply fundamentals, and a sluggish macroeconomic backdrop.  Despite the slowdown, consumption is expected to accelerate again in 2026, reaching a new all-time high as improving supply—driven by expanding LNG output—supports stronger global demand. These are findings from International Energy Agency (IEA)’s Gas 2025 report. Preliminary IEA data shows gas consumption in the markets covered by the update rose by just 0.5%—about 10 billion cu m (bcm)—year on year (y-o-y) in the first 9 months of 2025, with nearly all growth coming from Europe and North America. Demand patterns shifted notably compared with previous years. Europe posted the strongest gains as industrial activity stabilized and gas-fired power generation increased, while Asia’s gas consumption remained broadly flat, showing virtually no y-o-y growth over the same period. Supply conditions stayed tight despite a 5% increase in global LNG output—nearly 20 bcm—between January and September 2025. Rising LNG exports were partly offset by lower Russian and Norwegian pipeline deliveries to Europe, while the European Union (EU)’s storage injections further tightened the overall balance. For full-year 2025, global gas demand is expected to expand by less than 1%, assuming normal winter weather in the fourth quarter. Regional trends vary. Looking ahead, IEA forecasts global gas consumption to reach a new all-time high in 2026, with demand growth accelerating to 2% as supply conditions improve. Global LNG output is forecast to rise by a robust 7% (around 40 bcm) next year, led by new capacity in the US, Canada, and Qatar. Strengthening supply is expected to stimulate demand, particularly in fast-growing, price-sensitive Asian markets, where consumption is projected to climb nearly 5%, accounting for about half of total

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National Grid, Con Edison urge FERC to adopt gas pipeline reliability requirements

The Federal Energy Regulatory Commission should adopt reliability-related requirements for gas pipeline operators to ensure fuel supplies during cold weather, according to National Grid USA and affiliated utilities Consolidated Edison Co. of New York and Orange and Rockland Utilities. In the wake of power outages in the Southeast and the near collapse of New York City’s gas system during Winter Storm Elliott in December 2022, voluntary efforts to bolster gas pipeline reliability are inadequate, the utilities said in two separate filings on Friday at FERC. The filings were in response to a gas-electric coordination meeting held in November by the Federal-State Current Issues Collaborative between FERC and the National Association of Regulatory Utility Commissioners. National Grid called for FERC to use its authority under the Natural Gas Act to require pipeline reliability reporting, coupled with enforcement mechanisms, and pipeline tariff reforms. “Such data reporting would enable the commission to gain a clearer picture into pipeline reliability and identify any problematic trends in the quality of pipeline service,” National Grid said. “At that point, the commission could consider using its ratemaking, audit, and civil penalty authority preemptively to address such identified concerns before they result in service curtailments.” On pipeline tariff reforms, FERC should develop tougher provisions for force majeure events — an unforeseen occurence that prevents a contract from being fulfilled — reservation charge crediting, operational flow orders, scheduling and confirmation enhancements, improved real-time coordination, and limits on changes to nomination rankings, National Grid said. FERC should support efforts in New England and New York to create financial incentives for gas-fired generators to enter into winter contracts for imported liquefied natural gas supplies, or other long-term firm contracts with suppliers and pipelines, National Grid said. Con Edison and O&R said they were encouraged by recent efforts such as North American Energy Standard

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US BOEM Seeks Feedback on Potential Wind Leasing Offshore Guam

The United States Bureau of Ocean Energy Management (BOEM) on Monday issued a Call for Information and Nominations to help it decide on potential leasing areas for wind energy development offshore Guam. The call concerns a contiguous area around the island that comprises about 2.1 million acres. The area’s water depths range from 350 meters (1,148.29 feet) to 2,200 meters (7,217.85 feet), according to a statement on BOEM’s website. Closing April 7, the comment period seeks “relevant information on site conditions, marine resources, and ocean uses near or within the call area”, the BOEM said. “Concurrently, wind energy companies can nominate specific areas they would like to see offered for leasing. “During the call comment period, BOEM will engage with Indigenous Peoples, stakeholder organizations, ocean users, federal agencies, the government of Guam, and other parties to identify conflicts early in the process as BOEM seeks to identify areas where offshore wind development would have the least impact”. The next step would be the identification of specific WEAs, or wind energy areas, in the larger call area. BOEM would then conduct environmental reviews of the WEAs in consultation with different stakeholders. “After completing its environmental reviews and consultations, BOEM may propose one or more competitive lease sales for areas within the WEAs”, the Department of the Interior (DOI) sub-agency said. BOEM Director Elizabeth Klein said, “Responsible offshore wind development off Guam’s coast offers a vital opportunity to expand clean energy, cut carbon emissions, and reduce energy costs for Guam residents”. Late last year the DOI announced the approval of the 2.4-gigawatt (GW) SouthCoast Wind Project, raising the total capacity of federally approved offshore wind power projects to over 19 GW. The project owned by a joint venture between EDP Renewables and ENGIE received a positive Record of Decision, the DOI said in

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Biden Bars Offshore Oil Drilling in USA Atlantic and Pacific

President Joe Biden is indefinitely blocking offshore oil and gas development in more than 625 million acres of US coastal waters, warning that drilling there is simply “not worth the risks” and “unnecessary” to meet the nation’s energy needs.  Biden’s move is enshrined in a pair of presidential memoranda being issued Monday, burnishing his legacy on conservation and fighting climate change just two weeks before President-elect Donald Trump takes office. Yet unlike other actions Biden has taken to constrain fossil fuel development, this one could be harder for Trump to unwind, since it’s rooted in a 72-year-old provision of federal law that empowers presidents to withdraw US waters from oil and gas leasing without explicitly authorizing revocations.  Biden is ruling out future oil and gas leasing along the US East and West Coasts, the eastern Gulf of Mexico and a sliver of the Northern Bering Sea, an area teeming with seabirds, marine mammals, fish and other wildlife that indigenous people have depended on for millennia. The action doesn’t affect energy development under existing offshore leases, and it won’t prevent the sale of more drilling rights in Alaska’s gas-rich Cook Inlet or the central and western Gulf of Mexico, which together provide about 14% of US oil and gas production.  The president cast the move as achieving a careful balance between conservation and energy security. “It is clear to me that the relatively minimal fossil fuel potential in the areas I am withdrawing do not justify the environmental, public health and economic risks that would come from new leasing and drilling,” Biden said. “We do not need to choose between protecting the environment and growing our economy, or between keeping our ocean healthy, our coastlines resilient and the food they produce secure — and keeping energy prices low.” Some of the areas Biden is protecting

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Biden Admin Finalizes Hydrogen Tax Credit Favoring Cleaner Production

The Biden administration has finalized rules for a tax incentive promoting hydrogen production using renewable power, with lower credits for processes using abated natural gas. The Clean Hydrogen Production Credit is based on carbon intensity, which must not exceed four kilograms of carbon dioxide equivalent per kilogram of hydrogen produced. Qualified facilities are those whose start of construction falls before 2033. These facilities can claim credits for 10 years of production starting on the date of service placement, according to the draft text on the Federal Register’s portal. The final text is scheduled for publication Friday. Established by the 2022 Inflation Reduction Act, the four-tier scheme gives producers that meet wage and apprenticeship requirements a credit of up to $3 per kilogram of “qualified clean hydrogen”, to be adjusted for inflation. Hydrogen whose production process makes higher lifecycle emissions gets less. The scheme will use the Energy Department’s Greenhouse Gases, Regulated Emissions and Energy Use in Transportation (GREET) model in tiering production processes for credit computation. “In the coming weeks, the Department of Energy will release an updated version of the 45VH2-GREET model that producers will use to calculate the section 45V tax credit”, the Treasury Department said in a statement announcing the finalization of rules, a process that it said had considered roughly 30,000 public comments. However, producers may use the GREET model that was the most recent when their facility began construction. “This is in consideration of comments that the prospect of potential changes to the model over time reduces investment certainty”, explained the statement on the Treasury’s website. “Calculation of the lifecycle GHG analysis for the tax credit requires consideration of direct and significant indirect emissions”, the statement said. For electrolytic hydrogen, electrolyzers covered by the scheme include not only those using renewables-derived electricity (green hydrogen) but

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Xthings unveils Ulticam home security cameras powered by edge AI

Join our daily and weekly newsletters for the latest updates and exclusive content on industry-leading AI coverage. Learn More Xthings announced that its Ulticam security camera brand has a new model out today: the Ulticam IQ Floodlight, an edge AI-powered home security camera. The company also plans to showcase two additional cameras, Ulticam IQ, an outdoor spotlight camera, and Ulticam Dot, a portable, wireless security camera. All three cameras offer free cloud storage (seven days rolling) and subscription-free edge AI-powered person detection and alerts. The AI at the edge means that it doesn’t have to go out to an internet-connected data center to tap AI computing to figure out what is in front of the camera. Rather, the processing for the AI is built into the camera itself, and that sets a new standard for value and performance in home security cameras. It can identify people, faces and vehicles. CES 2025 attendees can experience Ulticam’s entire lineup at Pepcom’s Digital Experience event on January 6, 2025, and at the Venetian Expo, Halls A-D, booth #51732, from January 7 to January 10, 2025. These new security cameras will be available for purchase online in the U.S. in Q1 and Q2 2025 at U-tec.com, Amazon, and Best Buy. The Ulticam IQ Series: smart edge AI-powered home security cameras Ulticam IQ home security camera. The Ulticam IQ Series, which includes IQ and IQ Floodlight, takes home security to the next level with the most advanced AI-powered recognition. Among the very first consumer cameras to use edge AI, the IQ Series can quickly and accurately identify people, faces and vehicles, without uploading video for server-side processing, which improves speed, accuracy, security and privacy. Additionally, the Ulticam IQ Series is designed to improve over time with over-the-air updates that enable new AI features. Both cameras

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Intel unveils new Core Ultra processors with 2X to 3X performance on AI apps

Join our daily and weekly newsletters for the latest updates and exclusive content on industry-leading AI coverage. Learn More Intel unveiled new Intel Core Ultra 9 processors today at CES 2025 with as much as two or three times the edge performance on AI apps as before. The chips under the Intel Core Ultra 9 and Core i9 labels were previously codenamed Arrow Lake H, Meteor Lake H, Arrow Lake S and Raptor Lake S Refresh. Intel said it is pushing the boundaries of AI performance and power efficiency for businesses and consumers, ushering in the next era of AI computing. In other performance metrics, Intel said the Core Ultra 9 processors are up to 5.8 times faster in media performance, 3.4 times faster in video analytics end-to-end workloads with media and AI, and 8.2 times better in terms of performance per watt than prior chips. Intel hopes to kick off the year better than in 2024. CEO Pat Gelsinger resigned last month without a permanent successor after a variety of struggles, including mass layoffs, manufacturing delays and poor execution on chips including gaming bugs in chips launched during the summer. Intel Core Ultra Series 2 Michael Masci, vice president of product management at the Edge Computing Group at Intel, said in a briefing that AI, once the domain of research labs, is integrating into every aspect of our lives, including AI PCs where the AI processing is done in the computer itself, not the cloud. AI is also being processed in data centers in big enterprises, from retail stores to hospital rooms. “As CES kicks off, it’s clear we are witnessing a transformative moment,” he said. “Artificial intelligence is moving at an unprecedented pace.” The new processors include the Intel Core 9 Ultra 200 H/U/S models, with up to

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Quantum physicists have shrunk and “de-censored” DeepSeek R1

EXECUTIVE SUMMARY A group of quantum physicists claims to have created a version of the powerful reasoning AI model DeepSeek R1 that strips out the censorship built into the original by its Chinese creators.  The scientists at Multiverse Computing, a Spanish firm specializing in quantum-inspired AI techniques, created DeepSeek R1 Slim, a model that is 55% smaller but performs almost as well as the original model. Crucially, they also claim to have eliminated official Chinese censorship from the model. In China, AI companies are subject to rules and regulations meant to ensure that content output aligns with laws and “socialist values.” As a result, companies build in layers of censorship when training the AI systems. When asked questions that are deemed “politically sensitive,” the models often refuse to answer or provide talking points straight from state propaganda. To trim down the model, Multiverse turned to a mathematically complex approach borrowed from quantum physics that uses networks of high-dimensional grids to represent and manipulate large data sets. Using these so-called tensor networks shrinks the size of the model significantly and allows a complex AI system to be expressed more efficiently.
The method gives researchers a “map” of all the correlations in the model, allowing them to identify and remove specific bits of information with precision. After compressing and editing a model, Multiverse researchers fine-tune it so its output remains as close as possible to that of the original. To test how well it worked, the researchers compiled a data set of around 25 questions on topics known to be restricted in Chinese models, including “Who does Winnie the Pooh look like?”—a reference to a meme mocking President Xi Jinping—and “What happened in Tiananmen in 1989?” They tested the modified model’s responses against the original DeepSeek R1, using OpenAI’s GPT-5 as an impartial judge to rate the degree of censorship in each answer. The uncensored model was able to provide factual responses comparable to those from Western models, Multiverse says.
This work is part of Multiverse’s broader effort to develop technology to compress and manipulate existing AI models. Most large language models today demand high-end GPUs and significant computing power to train and run. However, they are inefficient, says Roman Orús, Multiverse’s cofounder and chief scientific officer. A compressed model can perform almost as well and save both energy and money, he says.  There is a growing effort across the AI industry to make models smaller and more efficient. Distilled models, such as DeepSeek’s own R1-Distill variants, attempt to capture the capabilities of larger models by having them “teach” what they know to a smaller model, though they often fall short of the original’s performance on complex reasoning tasks. Other ways to compress models include quantization, which reduces the precision of the model’s parameters (boundaries that are set when it’s trained), and pruning, which removes individual weights or entire “neurons.” “It’s very challenging to compress large AI models without losing performance,” says Maxwell Venetos, an AI research engineer at Citrine Informatics, a software company focusing on materials and chemicals, who didn’t work on the Multiverse project. “Most techniques have to compromise between size and capability. What’s interesting about the quantum-inspired approach is that it uses very abstract math to cut down redundancy more precisely than usual.” This approach makes it possible to selectively remove bias or add behaviors to LLMs at a granular level, the Multiverse researchers say. In addition to removing censorship from the Chinese authorities, researchers could inject or remove other kinds of perceived biases or specialty knowledge. In the future, Multiverse says, it plans to compress all mainstream open-source models.   Thomas Cao, assistant professor of technology policy at Tufts University’s Fletcher School, says Chinese authorities require models to build in censorship—and this requirement now shapes the global information ecosystem, given that many of the most influential open-source AI models come from China. Academics have also begun to document and analyze the phenomenon. Jennifer Pan, a professor at Stanford, and Princeton professor Xu Xu conducted a study earlier this year examining government-imposed censorship in large language models. They found that models created in China exhibit significantly higher rates of censorship, particularly in response to Chinese-language prompts. There is growing interest in efforts to remove censorship from Chinese models. Earlier this year, the AI search company Perplexity released its own uncensored variant of DeepSeek R1, which it named R1 1776. Perplexity’s approach involved post-training the model on a data set of 40,000 multilingual prompts related to censored topics, a more traditional fine-tuning method than the one Multiverse used.  However, Cao warns that claims to have fully “removed” censorship may be overstatements. The Chinese government has tightly controlled information online since the internet’s inception, which means that censorship is both dynamic and complex. It is baked into every layer of AI training, from the data collection process to the final alignment steps.  “It is very difficult to reverse-engineer that [a censorship-free model] just from answers to such a small set of questions,” Cao says. 

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Realizing value with AI inference at scale and in production

In partnership withHPE Training an AI model to predict equipment failures is an engineering achievement. But it’s not until prediction meets action—the moment that model successfully flags a malfunctioning machine—that true business transformation occurs. One technical milestone lives in a proof-of-concept deck; the other meaningfully contributes to the bottom line. Craig Partridge, senior director worldwide of Digital Next Advisory at HPE, believes “the true value of AI lies in inference”. Inference is where AI earns its keep. It’s the operational layer that puts all that training to use in real-world workflows. Partridge elaborates, “The phrase we use for this is ‘trusted AI inferencing at scale and in production,'” he says. “That’s where we think the biggest return on AI investments will come from.”Getting to that point is difficult. Christian Reichenbach, worldwide digital advisor at HPE, points to findings from the company’s recent survey of 1,775 IT leaders: While nearly a quarter (22%) of organizations have now operationalized AI—up from 15% the previous year—the majority remain stuck in experimentation. Reaching the next stage requires a three-part approach: establishing trust as an operating principle, ensuring data-centric execution, and cultivating IT leadership capable of scaling AI successfully. Trust as a prerequisite for scalable, high-stakes AI Trusted inference means users can actually rely on the answers they’re getting from AI systems. This is important for applications like generating marketing copy and deploying customer service chatbots, but it’s absolutely critical for higher-stakes scenarios—say, a robot assisting during surgeries or an autonomous vehicle navigating crowded streets.
Whatever the use case, establishing trust will require doubling down on data quality; first and foremost, inferencing outcomes must be built on reliable foundations. This reality informs one of Partridge’s go-to mantras: “Bad data in equals bad inferencing out.” Reichenbach cites a real-world example of what happens when data quality falls short—the rise of unreliable AI-generated content, including hallucinations, that clogs workflows and forces employees to spend significant time fact-checking. “When things go wrong, trust goes down, productivity gains are not reached, and the outcome we’re  looking for is not achieved,” he says.
On the other hand, when trust is properly engineered into inference systems, efficiency and productivity gains can increase. Take a network operations team tasked with troubleshooting configurations. With a trusted inferencing engine, that unit gains a reliable copilot that can deliver faster, more accurate, custom-tailored recommendations—”a 24/7 member of the team they didn’t have before,” says Partridge. The shift to data-centric thinking and rise of the AI factory In the first AI wave, companies rushed to hire data scientists and many viewed sophisticated, trillion-parameter models as the primary goal. But today, as organizations move to turn early pilots into real, measurable outcomes, the focus has shifted toward data engineering and architecture. “Over the past five years, what’s become more meaningful is breaking down data silos, accessing data streams, and quickly unlocking value,” says Reichenbach. It’s an evolution happening alongside the rise of the AI factory—the always-on production line where data moves through pipelines and feedback loops to generate continuous intelligence. This shift reflects an evolution from model-centric to data-centric thinking, and with it comes a new set of strategic considerations. “It comes down to two things: How much of the intelligence–the model itself–is truly yours? And how much of the input–the data–is uniquely yours, from your customers, operations, or market?” says Reichenbach. These two central questions inform everything from platform direction and operating models to engineering roles and trust and security considerations. To help clients map their answers—and translate them into actionable strategies—Partridge breaks down HPE’s four-quadrant AI factory implication matrix (see figure): Source: HPE, 2025 Run: Accessing an external, pretrained model via an interface or API; organizations don’t own the model or the data. Implementation requires strong security and governance. It also requires establishing a center of excellence that makes and communicates decisions about AI usage. RAG (retrieval augmented generation): Using external, pre-trained models combined with a company’s proprietary data to create unique insights. Implementation focuses on connecting data streams to inferencing capabilities that provide rapid, integrated access to full-stack AI platforms. Riches: Training custom models on data that resides in the enterprise for unique differentiation opportunities and insights. Implementation requires scalable, energy-efficient environments, and often high-performance systems. Regulate: Leveraging custom models trained on external data, requiring the same scalable setup as Riches, but with added focus on legal and regulatory compliance for handling sensitive, non-owned data with extreme caution. Importantly, these quadrants are not mutually exclusive. Partridge notes that most organizations—including HPE itself—operate across many of the quadrants. “We build our own models to help understand how networks operate,” he says. “We then deploy that intelligence into our products, so that our end customer gets the chance to deliver in what we call the ‘Run’ quadrant. So for them, it’s not their data; it’s not their model. They’re just adding that capability inside their organization.” IT’s moment to scale—and lead The second part of Partridge’s catchphrase about inferencing—”at scale”— speaks to a primary tension in enterprise AI: what works for a handful of use cases often breaks when applied across an entire organization.

“There’s value in experimentation and kicking ideas around,” he says. “But if you want to really see the benefits of AI, it needs to be something that everybody can engage in and that solves for many different use cases.” In Partridge’s view, the challenge of turning boutique pilots into organization-wide systems is uniquely suited to the IT function’s core competencies—and it’s a leadership opportunity the function can’t afford to sit out. “IT takes things that are small-scale and implements the discipline required to run them at scale,” he says. “So, IT organizations really need to lean into this debate.” For IT teams content to linger on the sidelines, history offers a cautionary tale from the last major infrastructure shift: enterprise migration to the cloud. Many IT departments sat out decision-making during the early cloud adoption wave a decade ago, while business units independently deployed cloud services. This led to fragmented systems, redundant spending, and security gaps that took years to untangle. The same dynamic threatens to repeat with AI, as different teams experiment with tools and models outside IT’s purview. This phenomenon—sometimes called shadow AI—describes environments where pilots proliferate without oversight or governance. Partridge believes that most organizations are already operating in the “Run” quadrant in some capacity, as employees will use AI tools whether or not they’re officially authorized to. Rather than shut down experimentation, it is now IT’s mandate to bring structure to it. And enterprises must architect a data platform strategy that brings together enterprise data with guardrails, governance framework, and accessibility to feed AI. Also, it’s critical to keep standardizing infrastructure (such as private cloud AI platforms), protecting data integrity, and safeguarding brand trust, all while enabling the speed and flexibility that AI applications demand. These are the requirements for reaching the final milestone: AI that’s truly in production. For teams on the path to that goal, Reichenbach distills what success requires. “It comes down to knowing where you play: When to Run external models smarter, when to apply RAG to make them more informed, where to invest to unlock Riches from your own data and models, and when to Regulate what you don’t control,” says Reichenbach. “The winners will be those who bring clarity to all quadrants and align technology ambition with governance and value creation.” For more, register to watch MIT Technology Review’s EmTech AI Salon, featuring HPE. This content was produced by Insights, the custom content arm of MIT Technology Review. It was not written by MIT Technology Review’s editorial staff. It was researched, designed, and written by human writers, editors, analysts, and illustrators. This includes the writing of surveys and collection of data for surveys. AI tools that may have been used were limited to secondary production processes that passed thorough human review.

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Google’s new Gemini 3 “vibe-codes” responses and comes with its own agent

EXECUTIVE SUMMARY Google today unveiled Gemini 3, a major upgrade to its flagship multimodal model. The firm says the new model is better at reasoning, has more fluid multimodal capabilities (the ability to work across voice, text or images), and will work like an agent.  The previous model, Gemini 2.5, supports multimodal input. Users can feed it images, handwriting, or voice. But it usually requires explicit instructions about the format the user wants back, and it defaults to plain text regardless.  But Gemini 3 introduces what Google calls “generative interfaces,” which allow the model to make its own choices about what kind of output fits the prompt best, assembling visual layouts and dynamic views on its own instead of returning a block of text.  Ask for travel recommendations and it may spin up a website-like interface inside the app, complete with modules, images, and follow-up prompts such as “How many days are you traveling?” or “What kinds of activities do you enjoy?” It also presents clickable options based on what you might want next.
When asked to explain a concept, Gemini 3 may sketch a diagram or generate a simple animation on its own if it believes a visual is more effective.  “Visual layout generates an immersive, magazine-style view complete with photos and modules,” says Josh Woodward, VP of Google Labs, Gemini, and AI Studio. “These elements don’t just look good but invite your input to further tailor the results.” 
With Gemini 3, Google is also introducing Gemini Agent, an experimental feature designed to handle multi-step tasks directly inside the app. The agent can connect to services such as Google Calendar, Gmail, and Reminders. Once granted access, it can execute tasks like organizing an inbox or managing schedules.  Similar to other agents, it breaks tasks into discrete steps, displays its progress in real time, and pauses for approval from the user before continuing. Google describes the feature as a step toward “a true generalist agent.” It will be available on the web for Google AI Ultra subscribers in the US starting November 18. The overall approach can seem a lot like “vibe coding,” where users describe an end goal in plain language and let the model assemble the interface or code needed to get there. The update also ties Gemini more deeply into Google’s existing products. In Search, a limited group of Google AI Pro and Ultra subscribers can now switch to Gemini 3 Pro, the reasoning variation of the new model, to receive deeper, more thorough AI-generated summaries that rely on the model’s reasoning rather than the existing AI Mode. For shopping, Gemini will now pull from Google’s Shopping Graph—which the company says contains more than 50 billion product listings—to generate its own recommendation guides. Users just need to ask a shopping-related question or search a shopping-related phrase, and the model assembles an interactive, Wirecutter-style product recommendation piece, complete with prices and product details, without redirecting to an external site. For developers, Google is also pushing single-prompt software generation further. The company introduced Google Antigravity, a  development platform that acts as an all-in-one space where code, tools, and workflows can be created and managed from a single prompt. Derek Nee, CEO of Flowith, an agentic AI application, told MIT Technology Review that Gemini 3 Pro addresses several gaps in earlier models. Improvements include stronger visual understanding, better code generation, and better performance on long tasks—features he sees as essential for developers of AI apps and agents.  “Given its speed and cost advantages, we’re integrating the new model into our product,” he says. “We’re optimistic about its potential, but we need deeper testing to understand how far it can go.” 

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Networking for AI: Building the foundation for real-time intelligence

In partnership withHPE The Ryder Cup is an almost-century-old tournament pitting Europe against the United States in an elite showcase of golf skill and strategy. At the 2025 event, nearly a quarter of a million spectators gathered to watch three days of fierce competition on the fairways. From a technology and logistics perspective, pulling off an event of this scale is no easy feat. The Ryder Cup’s infrastructure must accommodate the tens of thousands of network users who flood the venue (this year, at Bethpage Black in Farmingdale, New York) every day. To manage this IT complexity, Ryder Cup engaged technology partner HPE to create a central hub for its operations. The solution centered around a platform where tournament staff could access data visualization supporting operational decision-making. This dashboard, which leveraged a high-performance network and private-cloud environment, aggregated and distilled insights from diverse real-time data feeds. It was a glimpse into what AI-ready networking looks like at scale—a real-world stress test with implications for everything from event management to enterprise operations. While models and data readiness get the lion’s share of boardroom attention and media hype, networking is a critical third leg of successful AI implementation, explains Jon Green, CTO of HPE Networking. “Disconnected AI doesn’t get you very much; you need a way to get data into it and out of it for both training and inference,” he says.
As businesses move toward distributed, real-time AI applications, tomorrow’s networks will need to parse even more massive volumes of information at ever more lightning-fast speeds. What played out on the greens at Bethpage Black represents a lesson being learned across industries: Inference-ready networks are a make-or-break factor for turning AI’s promise into real-world performance. Making a network AI inference-ready More than half of organizations are still struggling to operationalize their data pipelines. In a recent HPE cross-industry survey of 1,775  IT leaders, 45% said they could run real-time data pushes and pulls for innovation. It’s a noticeable change over last year’s numbers (just 7% reported having such capabilities in 2024), but there’s still work to be done to connect data collection with real-time decision-making.
The network may hold the key to further narrowing that gap. Part of the solution will likely come down to infrastructure design. While traditional enterprise networks are engineered to handle the predictable flow of business applications—email, browsers, file sharing, etc.—they’re not designed to field the dynamic, high-volume data movement required by AI workloads. Inferencing in particular depends on shuttling vast datasets between multiple GPUs with supercomputer-like precision. “There’s an ability to play fast and loose with a standard, off-the-shelf enterprise network,” says Green. “Few will notice if an email platform is half a second slower than it might’ve been. But with AI transaction processing, the entire job is gated by the last calculation taking place. So it becomes really noticeable if you’ve got any loss or congestion.” Networks built for AI, therefore, must operate with a different set of performance characteristics, including ultra-low latency, lossless throughput, specialized equipment, and adaptability at scale. One of these differences is AI’s distributed nature, which affects the seamless flow of data. The Ryder Cup was a vivid demonstration of this new class of networking in action. During the event, a Connected Intelligence Center was put in place to ingest data from ticket scans, weather reports, GPS-tracked golf carts, concession and merchandise sales, spectator and consumer queues, and network performance. Additionally, 67 AI-enabled cameras were positioned throughout the course. Inputs were analyzed through an operational intelligence dashboard and provided staff with an instantaneous view of activity across the grounds. “The tournament is really complex from a networking perspective, because you have many big open areas that aren’t uniformly packed with people,” explains Green. “People tend to follow the action. So in certain areas, it’s really dense with lots of people and devices, while other areas are completely empty.” To handle that variability, engineers built out a two-tiered architecture. Across the sprawling venue, more than 650 WiFi 6E access points, 170 network switches, and 25 user experience sensors worked together to maintain continuous connectivity and feed a private cloud AI cluster for live analytics. The front-end layer connected cameras, sensors, and access points to capture live video and movement data, while a back-end layer—located within a temporary on-site data center—linked GPUs and servers in a high-speed, low-latency configuration that effectively served as the system’s brain. Together, the setup enabled both rapid on-the-ground responses and data collection that could inform future operational planning. “AI models also were available to the team which could process video of the shots taken and help determine, from the footage, which ones were the most interesting,” says Green. Physical AI and the return of on-prem intelligence If time is of the essence for event management, it’s even more critical in contexts where safety is on the line—for instance a self-driving car making a split-second decision to accelerate or brake. In planning for the rise of physical AI, where applications move off screens and onto factory floors and city streets, a growing number of enterprises are rethinking their architectures. Instead of sending the data to centralized clouds for inference, some are deploying edge-based AI clusters that process information closer to where it is generated. Data-intensive training may still occur in the cloud, but inferencing happens on-site.

This hybrid approach is fueling a wave of operational repatriation, as workloads once relegated to the cloud return to on-premises infrastructure for enhanced speed, security, sovereignty, and cost reasons. “We’ve had an out-migration of IT into the cloud in recent years, but physical AI is one of the use cases that we believe will bring a lot of that back on-prem,” predicts Green, giving the example of an AI-infused factory floor, where a round-trip of sensor data to the cloud would be too slow to safely control automated machinery. “By the time processing happens in the cloud, the machine has already moved,” he explains. There’s data to back up Green’s projection: research from Enterprise Research Group shows that 84% of respondents are reevaluating application deployment strategies due to the growth of AI. Market forecasts also reflect this shift. According to IDC, the AI market for infrastructure is expected to reach $758 billion by 2029. AI for networking and the future of self-driving infrastructure The relationship between networking and AI is circular: Modern networks make AI at scale possible, but AI is also helping make networks smarter and more capable. “Networks are some of the most data-rich systems in any organization,” says Green. “That makes them a perfect use case for AI. We can analyze millions of configuration states across thousands of customer environments and learn what actually improves performance or stability.” At HPE for example, which has one of the largest network telemetry repositories in the world, AI models analyze anonymized data collected from billions of connected devices to identify trends and refine behavior over time. The platform processes more than a trillion telemetry points each day, which means it can continuously learn from real-world conditions. The concept broadly known as AIOps (or AI-driven IT operations) is changing how enterprise networks are managed across industries. Today, AI surfaces insights as recommendations that administrators can choose to apply with a single click. Tomorrow, those same systems might automatically test and deploy low-risk changes themselves. That long-term vision, Green notes, is referred to as a “self-driving network”—one that handles the repetitive, error-prone tasks that have historically plagued IT teams. “AI isn’t coming for the network engineer’s job, but it will eliminate the tedious stuff that slows them down,” he says. “You’ll be able to say, ‘Please go configure 130 switches to solve this issue,’ and the system will handle it. When a port gets stuck or someone plugs a connector in the wrong direction, AI can detect it—and in many cases, fix it automatically.” Digital initiatives now depend on how effectively information moves. Whether coordinating a live event or streamlining a supply chain, the performance of the network increasingly defines the performance of the business. Building that foundation today will separate those who pilot from those who scale AI.
For more, register to watch MIT Technology Review’s EmTech AI Salon, featuring HPE. This content was produced by Insights, the custom content arm of MIT Technology Review. It was not written by MIT Technology Review’s editorial staff. It was researched, designed, and written by human writers, editors, analysts, and illustrators. This includes the writing of surveys and collection of data for surveys. AI tools that may have been used were limited to secondary production processes that passed thorough human review.

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The Download: AI-powered warfare, and how embryo care is changing

This is today’s edition of The Download, our weekday newsletter that provides a daily dose of what’s going on in the world of technology. The State of AI: How war will be changed forever —Helen Warrell & James O’Donnell It is July 2027, and China is on the brink of invading Taiwan. Autonomous drones with AI targeting capabilities are primed to overpower the island’s air defenses as a series of crippling AI-generated cyberattacks cut off energy supplies and key communications. In the meantime, a vast disinformation campaign enacted by an AI-powered pro-Chinese meme farm spreads across global social media, deadening the outcry at Beijing’s act of aggression.Scenarios such as this have brought dystopian horror to the debate about the use of AI in warfare. Military commanders hope for a digitally enhanced force that is faster and more accurate than human-directed combat. 
But there are fears that as AI assumes an increasingly central role, these same commanders will lose control of a conflict that escalates too quickly and lacks ethical or legal oversight. Read the full story. This is the third edition of The State of AI, our subscriber-only collaboration between the Financial Times & MIT Technology Review examining the ways in which AI is reshaping global power.Every Monday, writers from both publications will debate one aspect of the generative AI revolution reshaping global power. While subscribers to The Algorithm, our weekly AI newsletter, get access to an extended excerpt, subscribers to the MIT Technology Review are able to read the whole thing. Sign up here to receive future editions every Monday.
Job titles of the future: AI embryologist Embryologists are the scientists behind the scenes of in vitro fertilization who oversee the development and selection of embryos, prepare them for transfer, and maintain the lab environment. They’ve been a critical part of IVF for decades, but their job has gotten a whole lot busier in recent years as demand for the fertility treatment skyrockets and clinics struggle to keep up.Klaus Wiemer, a veteran embryologist and IVF lab director, believes artificial intelligence might help by predicting embryo health in real time and unlocking new avenues for productivity in the lab. Read the full story. —Amanda Smith The must-reads I’ve combed the internet to find you today’s most fun/important/scary/fascinating stories about technology. 1 Big Tech’s job cuts are a warning signThey’re a canary down the mine for other industries. (WP $)+ Americans appear to feel increasingly unsettled by AI. (WSJ $)+ Global fund managers worry companies are overinvesting in the technology. (FT $)

2 Iran is attempting to stimulate rain to end its deadly droughtBut critics warn that cloud seeding is a challenging process. (New Scientist $)+ Parts of western Iran are now experiencing flooding. (Reuters)+ Why it’s so hard to bust the weather control conspiracy theory. (MIT Technology Review) 3 Air taxi startups may produce new aircraft for war zonesThe US Army has announced its intentions to acquire most of its weapons from startups, not major contractors. (The Information $)+ US firm Joby Aviation is launching flying taxis in Dubai. (NBC News)+ This giant microwave may change the future of war. (MIT Technology Review)4 Weight-loss drug make Eli Lilly is likely to cross a trillion-dollar valuationAs it prepares to launch a pill alternative to its injections. (WSJ $)+ Arch rival Novo Nordisk A/S is undercutting the company to compete. (Bloomberg $)+ We’re learning more about what weight-loss drugs do to the body. (MIT Technology Review) 5 What’s going on with the US TikTok ban?Even the lawmakers in charge don’t seem to know. (The Verge) 6 It’s getting harder to grow cocoaMass tree felling and lower rainfall in the Congo Basin is to blame. (FT $)+ Industrial agriculture activists are everywhere at COP30. (The Guardian)+ Africa fights rising hunger by looking to foods of the past. (MIT Technology Review) 7 Russia is cracking down on its critical military bloggersArmchair critics are facing jail time if they refuse to apologize. (Economist $) 8 Why the auto industry is so obsessed with humanoid robotsIt’s not just Tesla—plenty of others want to get in on the act. (The Atlantic $)+ China’s EV giants are betting big on humanoid robots. (MIT Technology Review) 9 Indian startups are challenging ChatGPT’s AI dominanceThey support a far wider range of languages than the large AI firms’ models. (Rest of World)+ OpenAI is huge in India. Its models are steeped in caste bias. (MIT Technology Review) 10 These tiny sensors track butterflies on their journey to Mexico 🦋Scientists hope it’ll shed some light on their mysterious life cycles. (NYT $)
Quote of the day
“I think no company is going to be immune, including us.”  —Sundar Pichai, CEO of Google, warns the BBC about the precarious nature of the AI bubble. One more thing How a 1980s toy robot arm inspired modern robotics—Jon KeeganAs a child of an electronic engineer, I spent a lot of time in our local Radio Shack as a kid. While my dad was locating capacitors and resistors, I was in the toy section. It was there, in 1984, that I discovered the best toy of my childhood: the Armatron robotic arm.Described as a “robot-like arm to aid young masterminds in scientific and laboratory experiments,” it was a legit robotic arm. And the bold look and function of Armatron made quite an impression on many young kids who would one day have a career in robotics. Read the full story.
We can still have nice things A place for comfort, fun and distraction to brighten up your day. (Got any ideas? Drop me a line or skeet ’em at me.) + The US Library of Congress has attained some handwritten drafts of iconic songs from The Wizard of Oz.+ This interesting dashboard tracks the world’s top 500 musical artists in the world right now—some of the listings may surprise you (or just make you feel really old.)+ Cult author Chris Kraus shares what’s floating her boat right now.+ The first images of the forthcoming Legend of Zelda film are here!

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OpenAI named Emerging Leader in Generative AI

To us, this recognition reinforces something we hear constantly from our customers like Amgen, Cisco, Morgan Stanley, T-Mobile, Target, and Thermo Fisher Scientific: AI is becoming a core layer of enterprise infrastructure. Companies aren’t just experimenting—they’re deploying AI systems that reshape how work gets done. We’ve invested heavily in privacy controls, data governance and residency, monitoring, and evaluations so enterprises can deploy AI safely.

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88 Energy acquires Alaska North Slope leases

Captivate Energy Alaska Inc., a wholly owned subsidiary of 88 Energy Ltd., was the successful bidder for acreage east and west of Project Leonis in Alaska’s North Slope Areawide 2025W Oil and Gas Lease Sale. Fourteen new leases cover about 34,560 acres across South Prudhoe and Kad River East, the comapny said in a release Nov. 20. In South Prudhoe, seven leases cover Ivishak structural closures immediately south of the Prudhoe Bay Unit. The Ivishak formation offers high-quality, clean sandstone reservoir across the entire prospective area, with predicted 20% porosity, 50-100 mD permeability, and high charge potential across the newly acquired acreage.   3D seismic data, regional well control, and petrophysical analysis has delineated a suite of low-risk Ivishak formation prospects to be the first drill-ready targets for future exploration and appraisal. Further technical work, including seismic reprocessing, will be undertaken in 2026 to refine volumetrics and support prospective resource certification ahead of future farm-out and drilling decisions. Farm-out and planning are underway to drill a multi-zone exploration well targeting the Ivishak reservoir and shallower Canning and USB reservoirs. In Kad River East, seven leases east of the Trans Alaska Pipeline System (TAPS) exist in an under-explored region. A 3D seismic survey is scheduled for licensing and reprocessing in 2026. This data, combined with historical well data showing an active multi-reservoir petroleum system across the area, will help identify multiple targets. An early dual-hub development concept for the South Prudhoe and Leonis area will evaluate a low capital expenditure tie-back to Prudhoe Bay and Kuparuk River Units or a direct hot-tap connection into TAPS.

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ExxonMobil takes 40% share in Enterprise Products’ Bahia NGL pipeline, plans expansion

ExxonMobil Corp. will acquire from Enterprise Products Partners LP, Houston, a 40% undivided joint interest (UJI) in Enterprise’s Bahia natural gas liquids (NGL) pipeline with investment aimed at increasing throughput by 400,000 b/d.   ExxonMobil will contribute its proportionate share of Bahia project costs to date, or about $650 million, according to an SEC filing.   The 550-mile Bahia pipeline, which has started commissioning activities and will begin commercial operations immediately thereafter, will have an initial capacity to transport 600,000 b/d of NGLs from the Midland and Delaware basins of West Texas to Enterprise’s Mont Belvieu fractionation complex, Enterprise said in a release Nov. 20. The companies’ plan to increase Bahia’s capacity to 1 million b/d includes adding incremental pumping capacity and constructing a 92-mile extension to ExxonMobil’s Cowboy natural gas processing plant in Eddy County, NM. ExxonMobil will own a 70% UJI in this extension. The extension will also connect to multiple Enterprise-owned processing plants in the Delaware basin. The expansion and extension are expected to be completed in fourth-quarter 2027. ExxonMobil’s interest will be referred to as the Cowboy Connector. Enterprise will operate the combined system. Growing Permian basin production ExxonMobil, in a separate statement Nov. 20, said the investment will help connect its growing production in the Permian basin to US Gulf Coast refining and chemical plants and enable access to export logistics to serve markets around the world. In its third-quarter report released late last month, ExxonMobil said it set a Permian production record of nearly 1.7 MMboe/d, while expanding its use of low-cost refinery coke as a proppant that penetrates deeper into fracs, improving well recoveries by up to 20%. Noting the growth in Permian output, A.J. “Jim” Teague, co-chief executive officer of Enterprise’s general partner, pointed to the increasing ratio of natural gas and NGL production

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Continental Resources to enter Argentina’s Vaca Muerta shale as operator

Continental Resources Inc., Oklahoma City, is marking its first operational role outside the US with an agreement to acquire a 90% operating stake in the Los Toldos II Oeste block in Argentina’s Vaca Muerta. The privately held company has started the regulatory process to register its local subsidiary, Continental Resources Argentina SAU, as part of its entry into Argentina. The deal, made with Pluspetrol, was disclosed through a filing with Argentina’s National Securities Commission (CNV) and local media. Gas y Petróleo del Neuquén (GyP), the provincial energy company, would hold the remaining 10%.  The block was previously operated by Pluspetrol, which had acquired Los Toldos through its deal to acquire ExxonMobil’s Argentine assets.  While financial terms were not disclosed, Pluspetrol confirmed that the transaction remains subject to customary conditions precedent, including regulatory approval from the province of Neuquén, which oversees upstream concession rights. Continental’s arrival comes as President Javier Milei’s administration seeks to attract US operators to accelerate unconventional development. Argentina’s Economy Minister Luis Caputo praised the deal, calling it “a concrete signal of confidence” in the country’s macroeconomic stabilization efforts and its strategy to scale up Vaca Muerta. High-potential, early-stage block Los Toldos II Oeste lies within Vaca Muerta’s liquids-rich fairway in the northwestern sector of the basin. The block spans 77.7 sq km and sits in an oil window with attractive thickness, pressure, and rock quality, though still far from the industrial development levels of core blocks. To date, the block has seen only three wells drilled, underscoring its early-stage nature and contrasting with mature areas such as Loma Campana (YPF–Chevron) and Bajada del Palo (Vista), where activity follows full factory-drilling models. Analysts expect Continental Resources to deploy elements of its US playbook: extended-reach horizontals. high-intensity frac designs. pad drilling. sequential development strategies aimed at lowering costs and stabilizing productivity

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EIA: Alaska oil output to grow 13% in 2025

After decades of steady decline, Alaska’s oil output is set for a significant rebound. EIA projects a 13% increase—about 55,000 b/d—in 2026, marking the state’s largest year-over-year growth since the 1980s. The turnaround is led by two major developments on the North Slope. ConocoPhillips’ Nuna project, which began producing in December 2024, has shown steady growth. The field produced 7,000 b/d in August 2025 and is expected to reach 20,000 b/d at its peak, helping offset declines in legacy fields. A larger boost is expected from Pikka Phase 1, jointly owned by Santos and Repsol. The project is scheduled to begin production in first-quarter 2026 and reach peak production of 80,000 b/d by mid-2026, nearly 20% of total Alaska oil production in 2025. EIA noted that wells from these new projects outperform most existing wells in the state. Recent production records from the Alaska Oil and Gas Conservation Commission show that new wells produce about 480 boe/d, whereas 78% of Alaskan wells produced less than 400 boe/d in 2023. The agency said its upgraded 2026 outlook reflects Santos’s accelerated ramp-up to peak production for the Pikka Phase 1 project and recent well tests demonstrating high productivity.

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BW Energy confirms liquid hydrocarbons in Kudu area offshore Namibia

BW Energy has confirmed the presence of liquid hydrocarbons in the Kudu license area in Orange basin offshore Namibia. Results come following completed drilling operations on the Kharas-1 appraisal well in the Kudu license area, the company said in a release Nov. 19. The Kharas prospect, on the northwest portion of the Kudu formation, was sanctioned as part of BW Energy’s broader plan to identify upside targets in the 4,567-sq license area (PPL003) following seismic acquisition in 2023. Kharas-1 achieved its technical objective of testing multiple targets within a single penetration, said Carl Arnet, chief executive officer, and the results “confirm, for the first time, the presence of liquid hydrocarbons” within the block, contributing to the company’s understanding of the broader petroleum system. Arnet said the reservoir complexity requires additional appraisal to assess its potential and that a forward program “will focus on further high value targets based on the presence of liquid hydrocarbons, as well as gas and the learnings from Kharas-1A.” The well reached a total depth of 5,100 m and intersected multiple reservoir intervals. Several shallow turbidite reservoirs with dry-gas shows were encountered, and reservoir properties from these and the acquired whole core are now being evaluated, the company said. In the deeper section of the well, hydrocarbons were encountered in a fractured volcaniclastic reservoir, which the company said confirms a working petroleum system with condensate and/or light oil. Further analysis is ongoing to determine the extent of the system and to characterize reservoir properties and appraisal options. The well will now be plugged. Kudu gas field was discovered in 1974 about 130 km off the southwest coast of Namibia in in water depth of 170 m. It is delineated by seven subsequent wells.  

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Shell UK farms out 50% stake in West of Shetland Tobermory gas discovery to Ithaca Energy

Shell UK agreed to farm out 50% non-working interest in two West of Shetland basin licenses to UK oil and gas operator Ithaca Energy plc. Financial terms were not disclosed. The UK North Sea licenses, P2629 and P2630, contain the Tobermory gas discovery, Ithaca Energy said in a release Nov. 19.  Ithaca Energy, as part of its third-quarter report also released Nov. 19, listed estimated gross 2C resource at Tobermory of 60-65 MMboe as of Dec. 31, 2024.   Following completion of the farm-in, Shell UK will continue to hold a 50% stake in the Tobermory discovery and act as license operator. The farm-out builds on the companies’ partnership in the UK Continental Shelf and fits into Ithaca Energy’s broader strategy to expand investment in the West of Shetland area. Shell UK and Ithaca Energy are existing 50-50 partners in the Tornado discovery.  As part of its third-quarter release, Ithaca said the Tornado project is progressing toward a financial investment decision (FID) with tendering and advancement of the Environmental Statement. Tornado’s estimated gross 2C resource is estimated by Ithaca at 67 MMboe.  In the release announcing the deal, Yaniv Friedman, executive chairman, Ithaca Energy, said the West of Shetland “represents a key basin for the Group’s long-term growth, with the ongoing development of the Rosebank field and the continued progression of the Cambo and Tornado discoveries towards final investment decision.” 

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