The Ivanpah Thermal Solar Power Plant, Once a Marvel of Technology, Has Become an Expensive Boondoggle: Some Want it Shuttered, but California Says It is Still Needed

     The Ivanpah Thermal Solar Power Plant in the Mojave Desert in California near the Nevada border has been operational since 2014. Once the U.S. flagship for thermal solar power, the project has become obsolete, some argue, since solar PV technology has improved to the point where it is more economical than Ivanpah. Basically, the project has become a stranded asset, more expensive to operate than deploying and operating existing solar PV tech. The current debate about closing it down or not is basically a debate about who pays the $1.6 billion government loan payments, taxpayers if it is closed, or electricity ratepayers if it remains open. It also shows the irony that all the hoopla about fossil fuel assets becoming stranded assets can be applied to some clean energy projects as well. In this case, it is a very expensive project with $2.2 billion in government funding.

     Ivanpah’s land footprint is quite large at 4000 acres. It contains 350,000 mirrors on 170,000 heliostats. The mirrors blinded aircraft with the glare, so plane routes had to be diverted around them. While its capacity is nearly 400 MW, since it is a solar plant only operational during the day, its actual output was likely closer to 100 MW. A 400 MW natural gas plant would have an output closer to 250 MW.

     Michael Dorgan of Fox News wrote a detailed article about the issues facing the plant. He noted some of the environmental issues that the plant has triggered, including significant wildlife impacts:

“The project has also faced scrutiny over its environmental impact, with thousands of birds killed after flying through the plant’s concentrated solar beams — along with the destruction of large areas of desert land and displacement of desert tortoises.”

     Thus, while its environmental benefits compared to a comparable 100-200 MW natural gas unit are great in terms of air pollutants and carbon emissions, its large land footprint, desert impacts, and hot concentrated solar beams that are deadly for birds make it not so great for the local environment.  

     Dorgan notes that between $730 million and $780 million of the $1.6 billion government loan is left to be paid. The project also received a $539 million government grant that funded 30% of its construction. Keeping the plant open may require up to $100 million per year from ratepayers compared to currently available solar alternatives.

“Officials under both the Trump and Biden administrations, along with Pacific Gas & Electric (PG&E) — which buys electricity from the plant — have supported shutting it down. PG&E has described the contracts as part of an effort to reduce "uneconomic resources" in its energy portfolio, according to regulatory filings.”

     The California Public Utilities Commission (CPUC) rejected efforts to break the power contracts that the plant has with buyers. Shutting down the plant could create another stranded asset, that being the $300 million sunk into transmission to deliver its power, which was funded by ratepayers. CPUC also cites potential threats to grid reliability in light of increasing demand due to AI data centers as reasons to keep it open.

     Severin Borenstein, an energy economist at the University of California, Berkeley, told Fox News Digital that:

“…the project reflects the risks of investing in emerging energy technologies at scale.”

Mark Jacobson, a Stanford University energy systems expert (and an avid anti-fossil fuel advocate – I add),

“…contended the technology itself is not inherently flawed but lacks key features used in newer systems.”

"There’s no role for a concentrated solar plant without storage," Jacobson told Fox News Digital, noting that modern systems typically store energy for use at night — something Ivanpah cannot do.

“Jacobson added that while the plant may no longer be competitive with new projects, that does not necessarily mean it should be shut down.”

"It’s already built," he said. "So the question is whether it’s cheaper to keep it running than to replace it."

     Ivanpah has also suffered operational issues, which have further degraded its output. In 2023, the plant had a capacity factor, or utilization rate, of just 17%, making it comparable to a 68 MW power plant working 24 hours. When it was built, it was hoped that its capacity factor would be steady between 25 and 30%.

     The plant is about 50 miles from the nearest town, and people there say their own power bills are very high.     

     It was an interesting project in its time, but I am guessing it will be shuttered before too long, although nobody knows when. I wonder what they will do with all those mirrors when the plant is decommissioned. It doesn’t seem likely that the stranded transmission will be useful or fully powered except for other solar projects and perhaps geothermal projects. It was an early experiment that sort of worked but had issues and then succumbed to better tech, namely PV solar plus storage.

     Dorgan published another article a week later detailing the wildlife impacts of the plant, including evidence that the concentrated solar beams scorched birds. The final environmental impact statement for the project noted that there would be bird deaths and that they would be monitored. No penalties or fines are issued for the deaths as they are considered to be incidental. However, if someone were to intentionally kill some of those bird species, they could be heavily fined, up to $15,000 per bird. There have been some mitigation attempts, but mostly, there is just monitoring. It is estimated that over one thousand birds are killed annually.

 

    

 

References:

Obama-backed $2.2B green energy boondoggle leaves taxpayers on the hook. Michael Dorgan. Fox News. May 2, 2026. Obama-backed $2.2B green energy boondoggle leaves taxpayers on the hook

Regulators allow Obama-era solar plant to kill thousands of birds annually, investigation finds. Michael Dorgan. Fox News. May 9, 2026. Regulators allow Obama-era solar plant to kill thousands of birds annually, investigation finds

 

The Electric Power Research Institute (EPRI) Deploys Local AI Via a Dell Compact Supercomputer and a NVIDIA Superchip, Without Compromising Security or Control

     As AI technology works its way into many applications in many sectors, it will likely appear in different configurations. Companies and institutions that work with infrastructure, safety, and public trust have special needs for AI tech to be under control and secure. Veronica Thums of Dell Technology writes about the Electric Power Research Institute’s (EPRI) configuration for safe and secure “local” AI via a special Dell compact supercomputer and a NVIDIA superchip. EPRI is an energy and electricity research institute that is deeply involved in integrating AI and data center power loads with power grids. The author notes that:

“Data sensitivity, regulatory requirements, and the need for deep domain reasoning make cloud‑only approaches difficult to scale responsibly.”

“With the Dell Pro Max with GB10 equipped with the NVIDIA Grace Blackwell Superchip, EPRI can develop, test, and run custom AI workflows locally — unlocking new levels of insight while keeping sensitive information firmly on premises.”

     Aside from better control and security, there are more reasons to deploy local AI instead of cloud-based AI. There are exposure concerns with external networks. Some advantages of local AI are given below.

     As noted, the Dell Pro Max GB10 NVIDIA combo, which costs between $5500 and $6300 depending on the amount of storage, can provide high-tech AI at a reasonable price for local or on-premises applications.

“Powered by NVIDIA DGX OS, the GB10 system delivers a stable and fully integrated NVIDIA AI software stack, enabling researchers to develop AI tools locally using the same environment they would rely on in larger enterprise infrastructures. With the Grace Blackwell Superchip, acceleration becomes a catalyst for real productivity. Delivering rapid inference, fluid model execution, and smooth interaction with large, reasoning‑intensive datasets.”

“In early 2026, EPRI developed Power Chat, a prototype demonstrating how document-grounded AI assistant can run entirely on a compact supercomputer—the Dell Pro Max with GB10. Power Chat enables deep, conversational exploration of technical documents through a streamline interface and a fully local workflow designed for controlled environments.”

“The goal is a faster path to insight from large, dense documents, improving access to critical information and supporting decision-making.”

     The compact GB10 setup can replace larger and more expensive GPU servers. The system takes about 15 minutes to boot up, load the models, and encode documents into the KV cache. Below is a sample of an EPRI Power Chat query.

     NVIDIA provides several AI playbooks that provide instructions for running AI workloads on its GB10 Grace Blackwell Superchip.     

     With the success and advantages of this system for specific applications requiring data security and control, I am guessing that local AI options for organizations that have such requirements will be the wave of the future due to lower costs and better control.

     

References:

 

EPRI: Local AI for Energy Research. Veronica Thums. Dell Technologies. April 6, 2026. EPRI: Local AI for Energy Research | Dell

 

 

 

 

Tainted Marine Diesel Fuel Cut with Estonian Shale Oil Bought in Singapore is Causing Engine Problems and Breakdowns for Tankers: Undeclared Fuel Substitution is Fraud

      Singapore is the world’s largest hub for marine fuel. Apparently, the Iran War is really affecting fuel prices and supply since marine fuel has been found to be cut with Estonian shale oil, not a very applicable additive for marine diesel fuel. Those responsible for cutting the fuel should be criminally liable. At least three tankers have experienced engine problems and breakdowns due to the fuel additive. Before the Strait of Hormuz was disrupted, Singapore got 40% of its oil from the Middle East.

"The tainted blend can lead to“sludging,”, where fuel becomes more viscous. This can clog engines and cause them to stutter or even grind to a halt." 

     An article in The Telegraph explains the issue:

“The problem has been most evident in Singapore, the world’s biggest hub for marine fuel, with reports of vessels encountering engine issues after taking on supplies.”

“At least three oil tankers were among ships to have suffered sludging and fuel pump failure after refueling in the Asian port last month, Lloyd’s List reported.”

“Subsequent analysis revealed that regular marine fuel had been cut with shale oil from Estonia, which is regarded as too impure for most engines.”

     While some engines can handle fuel substitutions and additives, others can’t.

“Veritas Petroleum Services, a specialist testing agency, found increased levels of shale oil in 90,000 tons of fuel – enough to fill the tanks of 10 very large crude carriers – uploaded between February and March.”

“Marine insurer Skuld last week urged companies to vet suppliers and test bunker fuel in advance after identifying issues in Hong Kong and Malaysia, as well as Singapore.”

     The cost of marine fuel initially doubled after the Iran War began, but has dropped to about 50% above what it was before the war. Of course, that is no excuse for fraud. If the disruptions to fuel supplies coming out of the Middle East continue, the problem could get worse. Since tainted fuel could be a matter of success or failure for tankers, I am guessing they will be testing fuels every chance they get to avoid problems. As it stands now, the situation is unacceptable, and shipping companies should not have to endure it.

 

References:

 

Tankers break down as Iran war unleashes flood of tainted fuel. Christopher Jasper. The Telegraph. May 9, 2026. Tankers break down as Iran war unleashes flood of tainted fuel

 

The End of Single-Basin Dominance is Reshaping U.S. Energy, by BOK Financial: Whitepaper Summary & Review

    This whitepaper explores the maturing Permian Basin, where Tier 1 acreage will soon enough be drilled up. The authors ask and answer what will replace investment in the Permian Basin. The main answers given are Appalachia, Oklahoma’s Anadarko Basin, and the plays in the Rockies. There are opportunities in Southern basins as well. Appalachia’s Marcellus and Burket are natural gas plays. Its Utica play has a narrow oil & liquids window currently being dominated by EOG Resources, but most of its acreage is prospective for gas. The deep Utica in Pennsylvania is currently producing large per-well gas volumes.

 

The Southern Basins – Permian, Eagle Ford, Hayneville-Bossier

     Looking at the Southern basins, the Permian, Eagle Ford, and Haynesville are the biggest plays, and each has large fairways for drilling. The Haynesville-Bossier play is high-volume gas but also has higher drilling costs due to depth and high-temperature/high-pressure conditions. The Permian and Eagle Ford have oil and gas fairways, but the Permian is mostly oil with associated gas. In those basins, operators have shifted priorities:

“Rather than expansion, operators are now prioritizing scale, efficiency and returns. Most of the big players there are looking to consolidate, to become more concentrated and get higher returns and have scale in the area,”

     Larger operators are prioritizing their best acreage and selling off parts they don’t want. This sometimes creates opportunities for smaller companies to acquire and develop, or they may acquire non-operated assets.

“More notably, some operators are finding value not in building large operated positions, but in assembling acreage and non-operated interests that can be monetized through trades or sales.”

     The Eagle Ford, they note, is past its peak growth phase. Operators are mostly focused on efficiency. They note that sometimes cheaper drilling and completion costs can make some acreage economical that previously was not economical. Pipelines are often a constraint in the Permian. Capital markets have also become more demanding:

“And the increasing influence of capital markets is reshaping strategy across the board, with investors demanding stronger returns, disciplined spending and more resilient balance sheets.”

     Expansion is no longer a main goal in the Southern Basins, but efficiency is becoming key as”

“…strategic positioning, operational discipline and the ability to create value in a tighter, more consolidated market.”

 

Appalachia - Marcellus and Utica

     The Appalachian plays have plenty of running room and are expected to produce well for decades. They are currently producing a third of the nation’s natural gas at mid-30s BCF per day. One of the region’s biggest constraints has long been the ability to build multi-state pipelines, where there is more public opposition and regulatory hurdles than in the South and West. That does, however, increase in-basin opportunities for projects such as natural gas plants, data centers, hydrogen projects, and industrial opportunities. These in-basin projects could add 2-4 BCF per day of demand in the region over the next several years. Incremental pipeline expansions can help, slightly increasing the ever-important pipeline takeaway capacity. They note that technological advancements can turn Tier 2 acreage into Tier 1 acreage. Deep Utica produces very good economic results despite higher well costs. The Utica oil window in Ohio produces results comparable to the Permian Basin. They predict that Appalachian production could rise to the low-40s BCF per day.

 

Oklahoma – Mainly SCOOP/STACK and Anadarko Basin, but Other Plays as Well

     Plays in Oklahoma include the SCOOP and STACK plays in central Oklahoma and the Anadarko Basin plays in Western Oklahoma. The Anadarko’s Cherokee Shale play has garnered attention in recent years. Some features of the Oklahoma plays include low cost of entry, abundant pipeline takeaway capacity, and the availability in most areas of multiple hydrocarbons: oil, natural gas, and natural gas liquids, which give companies optionality when pricing changes. Another feature is that most of the area is drilled by smaller private companies, with few large public companies involved. However, they also note that there can be geological challenges in some areas, where very good wells can occur next to not-so-good wells. They don’t mention it, but high amounts of water production are also a feature of drilling in Oklahoma, so water handling and disposal costs can also affect economics.

 

Rockies – Powder River, Uinta, DJ, Williston, and Several Other Basins

     Here, they emphasize that the Rockies' plays offer consistency and repeatability, which are important for economics. They note that there are still vast, undrilled areas in these basins to explore.

“What we’re seeing isn’t opportunistic interest—it’s strategic repositioning,” Evangelista said. “Capital is following assets that can deliver steady returns over time, and the Rockies are screening well under that framework.”

“The constraints are well understood. Regulatory complexity at the state level, combined with infrastructure limitations and distance from key markets, can impact both timelines and economics.”

“Over the next few years, the region’s role will likely expand as operators prioritize durability over peak output. Success will depend on a disciplined approach: understanding local regulatory environments, deploying capital selectively and executing against long-term development plans.”

 

In Summary – Growth is No Longer the Goal: Capital discipline, Inventory Depth, and Working with Infrastructure Constraints are Now the Focus

     In most U.S. basins, the resource has been identified, and the once-important goal of growth through the drill bit has been replaced by capital discipline and efficient development. The Southern basin trends are consolidation and scale. The Appalachian imperative is dealing with the logistics of pipeline constraints. In Oklahoma, some growth is possible, with the advantages of getting in cheaply, having product optionality, and abundant takeaway capacity. The Rockies feature consistency and sizable inventory. Many operators are balancing plays in multiple basins, seeking not growth but value and consistent returns.

“That shift is influencing everything from capital allocation to deal-making. M&A activity, private equity reentry and portfolio rebalancing all point to a more diversified approach to basin exposure.”

“It also suggests a more nuanced future for U.S. energy development. No single basin is likely to dominate in the way the Permian has over the past decade. Instead, the next phase may well be defined by a network of complementary regions, each playing a distinct role depending on cost structure, infrastructure access and resource profile.”

References:

 

The end of single-basin dominance is reshaping U.S. energy. BOK Financial. 2026. he-20260427-BOK+Financial-Hart+Energy+White+Paper.pdf

 

 

Iraq Announces 8.8 Billion Barrel Oil Discovery Near Saudi Border: China’s ZhenHua Oil is the Operator and Expects to Accelerate Development, and a New Pipeline Will Deliver it to Jordan, Bypassing Hormuz

    

      The Iraqi Ministry of Oil has announced the discovery of a large oil field in the southern province of Najaf, near the border with Saudi Arabia. This is an important discovery and one of the biggest in recent years in Iraq, the fifth largest global oil producer and the third largest OPEC producer. Iraq has reserves of 145 billion barrels of oil, roughly 17% of total Middle Eastern reserves and 9% of global reserves. The country was producing about 4.5 million barrels per day before the Iran War, but its oil revenue has dropped by about 71% since then, resulting in billions of lost revenues. Of its total production, 3.5 million barrels per day were exported, 90% through the Strait of Hormuz. There may be more to come in the area in the future, as just one of the exploration blocks has estimated reserves of 8.8 billion barrels. A deal to explore the block was signed in October 2024.

     According to Euro News:

“According to data announced by the Ministry, drilling operations at the Shams-11 exploration well showed the presence of light crude oil, with an initial production capacity of 3,248 barrels per day.”

     The oil discovery was in the MUS formation at a depth of 1,916-1,965 meters. 2D seismic surveying for her project began in October 2025, and drilling of the Sham-1 well commenced in January 2026.

“The announcement was made during an official meeting between Iraqi Oil Minister Hayan Abdul Ghani and representatives from China's ZhenHua Oil, during which they reviewed progress at the Qurnain site and discussed advanced drilling techniques to increase the efficiency of exploration and production operations and accelerate development.”

“ZhenHua, through its subsidiary Qurnain Petroleum Limited, is the main operator of exploratory drilling and seismic survey operations in partnership with the Iraqi side.”

     The Chinese company plans to implement a rapid investment plan to accelerate development.

“Baghdad is working to accelerate a strategic project to build a pipeline linking Basra province in the south with the city of Haditha in Anbar province near the Syrian border, with a planned export capacity of 2.5 million barrels per day.”

“According to official data issued by the Ministry of Oil, Iraq's oil exports fell to 18.6 million barrels in March, generating revenues of $1.96 billion (€1.77bn) — a decline of around 71 per cent in revenue terms compared to February, when Iraq exported more than 99 million barrels and earned $6.81 billion (€6.15bn).”

     The Qurnain Block is shown on the map below in south-central Iraq, right along the Saudi border.

     Brian Wang for Next Big Future wrote about the planned pipelines that will bypass the Strait of Hormuz. He notes that right now about 8-8.5 million barrels in the region bypasses Hormuz, but that these projects, with expected timelines of 3-5 years, will increase that to 12-13 million barrels per day by then, and that new Iraqi plans could increase that by another 2-3 million barrels per day. The first two maps below show pipelines and planned pipelines to bypass Hormuz, respectively. The third map, from Kpler, shows the likely route of the Basra-Aqaba Pipeline, which is expected to cost $5 billion.

 "The 700-kilometer pipeline will run from Basra - home to some 66 percent of Iraq’s oil reserves - to the town of Haditha in Anbar, oil ministry Spokesperson Abdulsahib al-Hasnawi told the state-run Iraqi News Agency (INA)."

"The Basra-Hadith pipeline will be capable of transporting “around 2.5 million oil barrels per day and enable exports to three ports: Baniyas in Syria, Ceyhan in Turkey [on the Mediterranean] and Aqaba in Jordan [on the Red Sea],” Hasnawi added."

 

 

 

References:

 

Iraq announces huge oil find near Saudi border as Hormuz crisis bites. Chaima Chihi. Euro News. May 8, 2026. Iraq announces huge oil find near Saudi border as Hormuz crisis bites

New Oil Discovery at Qurnain Exploration Block. Iraq Business News. New Oil Discovery at Qurnain Exploration Block | Iraq Business News

Iraq gives go-ahead for Basra oil pipeline under deal with China. Nadim Kawach. AGBI. April 27, 2026. Iraq gives go-ahead for Basra oil pipeline under deal with China

Other Pipelines and Projects to Bypass Oil From Hormuz. Brian Wang. Next Big Future. May 5, 2026. Other Pipelines and Projects to Bypass Oil From Hormuz | NextBigFuture.com

Beyond Hormuz: The pipeline routes that could reshape Gulf oil flows. Victoria Grabenwöger. Kpler. Beyond Hormuz: The pipeline routes that could reshape Gulf Beyond Hormuz: The pipeline routes that could reshape Gulf oil flows | Kpler -

Iraq accelerates $5 billion Basra-Anbar oil pipeline amid push for new export routes: Ministry. Rudaw. May 1, 2026. Iraq accelerates $5 billion Basra-Anbar oil... | Rudaw.net

 

U.S. Receives Delivery of 1.7 Metric Tons of High-Assay Low-Enriched Uranium (HALEU) from Japan for Advanced Nuclear Reactors

      The U.S. has received 1.7 metric tons of high-assay low-enriched uranium (HALEU) from Japan, the largest single shipment ever coordinated by the National Nuclear Security Administration (NNSA). NNSA coordinated with Japan’s Ministry of Education, Culture, Sports, Science and Technology, and the Japan Atomic Energy Agency for the shipment.

     Interesting Engineering explains the importance of HALEU nuclear fuel:

“HALEU is considered a key fuel source for next-generation nuclear reactors. Unlike conventional reactor fuel, it contains a higher concentration of uranium-235, allowing advanced reactors to operate more efficiently, for longer periods, and with smaller reactor designs.”

      The shipment will advance the U.S. HALEU Availability Program. HALEU is a lower risk alternative to highly enriched uranium and plutonium and cannot be used for nuclear weapons. It can improve reactor efficiency while reducing reactor size and extending operating cycles. Japan no longer needed the HALEU after it closed its Fast Critical Assembly program. The UK’s Nuclear Transport Solutions and Civil Nuclear Constabulary assisted the transfer.

“The shipment also aligns with recent U.S. efforts to accelerate advanced nuclear reactor deployment and reduce reliance on foreign nuclear fuel supplies. Earlier policy initiatives have emphasized building a domestic nuclear fuel ecosystem capable of supporting commercial and national security reactor programs.”

“HALEU has become increasingly important as multiple U.S. companies race to commercialize small modular reactors and other advanced nuclear systems designed for power generation, industrial applications, and defense-related energy needs.”

     According to the DOE:

“HALEU is crucial for next-generation nuclear fuels. It is utilized in advanced reactor designs, enhances efficiency in research and medical isotope production, and promotes nuclear security and nonproliferation by reducing global reliance on weapons-grade highly enriched uranium (HEU) and plutonium.”

 

 

 

References:

 

U.S. receives record 1.7 metric tons of HALEU uranium shipment for advanced reactors. Neetika Walter.  Interesting Engineering. May 7, 2026. Japan sends 1.7 metric tons of HALEU fuel to power US reactors

U.S. Secures Largest-Ever HALEU Shipment to Power American Nuclear Industry. U.S. Dept. of Energy. National Nuclear Security Administration. U.S. Secures Largest-Ever HALEU Shipment to Power American Nuclear Industry | Department of Energy

 

 

Norway Re-Starts Production at Once Marginal Eirin Field, Showing That Commodity Prices Determine Value: However, There is Environmentalist Opposition to Re-Opening Old Fields

  

     Norway’s state oil & gas giant Equinor has recently restarted natural gas production at its Eirin Field. Once considered to be marginal and uneconomic in times of low energy prices, at present, with high natural gas prices in Europe, it is now profitable as long as prices remain high. The recoverable reserves at the Eirin Field are estimated at 27.6 million barrels of oil equivalent, not a large amount, but producible now. Eirin will extend production from the Gina Krog platform by seven years, from 2029 to 2036. The field is mostly gas with some liquids.

     According to Linda Kåda Høiland, senior vice president for late-life fields in Equinor:

"The project has given us important learnings on how to develop marginal discoveries quickly and profitably. Such subsea developments will be important for maintaining production and value creation from the Norwegian shelf in the future. Early collaboration, efficient decision-making processes and standardized solutions have been crucial to realizing Eirin in a short time. From the establishment of the project to the start of production, we have only spent three years," says Høiland.

     As noted below, the field was discovered in 1978 and then shelved. It was reactivated in 2023 after gas became a stronger need due to the discontinuation of planned EU imports of Russian pipelined gas. FID was made the same year.  

     The oilprice.com article by Jan-Thore Bergsagel notes that Eorin is emblematic of how geopolitics can reinvigorate resources once considered stranded due to low product pricing.

     The Gina Krog platform, through which Eirin production will be processed, is powered by electricity from shore, which makes its emissions much lower than those of other platforms.

“The bottom line: Eirin will not reshape global gas markets on its own, but it captures today’s energy reality perfectly—speed matters, infrastructure beats ideology, and Norway keeps quietly doing what Europe still needs most: delivering gas when it counts.”

     The success and speed of reviving the Eirin field likely influenced new plans to revive other old oil & gas fields in Norway’s North Sea fields. 

     In response to the current geopolitical turmoil in the Middle East, the Norwegian government has given its approval for oil and gas companies to explore in 70 new locations in the North Sea, Barents Sea and Norwegian Sea.

     The Guardian reports:

“The Albuskjell, Vest Ekofisk and Tommeliten Gamma gasfields in the North Sea were closed in 1998. The government plans to spend 19bn kroner (£1.5bn) on restarting them by the end of 2028 with production to continue until 2048.”

     Meanwhile, environmentalists and those on the political left have predictably slammed the plans to reopen old fields:

“The deputy leader and environment spokesperson for the Socialist Left party, Lars Haltbrekken, said the decision was madness and accused the government of greenwashing.”

“It shows that the government is once again blatantly ignoring environmental advice from its own experts,” he said. “All the talk about responsible oil extraction is nothing but nonsense. It’s greenwashing through and through, with vulnerable and important natural areas being put at risk with full awareness.”

     I have written previously about the debates to approve and resume exploration and development at the UK North Sea Roseband and Jackdaw fields, arguing that they should be developed. Equinor is a part of those projects as well.

     Below, the Guardian article notes that due to soaring natural gas and oil prices in Europe, old fields are becoming economic and oil & gas company profits, including Equinor’s, are up, so they can invest in revitalizing some of these fields as well as exploring for more.

“The company’s record fossil fuel production combined with surging market prices helped it to its highest quarterly profits since 2023, when Russia’s invasion of Ukraine caused a gas supply shock across Europe. Equinor expects the current disruption to last well beyond any end to hostilities.”

“Norway’s energy minister, Terje Aasland, said: “Norwegian production of oil and gas is an important contribution to energy security in Europe. Development of new gasfields helps Norway maintain high deliveries in the long term.”

“This has become more important after Russia’s full-scale invasion of Ukraine and the conflict in the Middle East.”

  

 

 

References:

 

Norway just switched on another gas lifeline for Europe. Jan-Thore Bergsagel. OilPrice.com. May 5, 2026. Norway just switched on another gas lifeline for Europe

Norwegian government attacked over decision to reopen North Sea gasfields. Miranda Bryant and Jillian Ambrose. The Guardian. May 6, 2026. Norwegian government attacked over decision to reopen North Sea gasfields | Oil | The Guardian

The Eirin field in production - more gas to Europe. Equinor. May 5, 2026. The Eirin field in production - more gas to Europe - Equinor

 

Fermi’s Seemingly Impending Downfall: Can the Project Be Revived or Sold? Exploits of the Filthy-Rich?

 

  

      I have written two posts on this blog about Fermi America’s ambitious projects to develop a massive AI data center campus near Amarillo, Texas, expected to include the deployment of 11 GW of power via natural gas, solar, nuclear, and batteries. The first post was about the announcement for the huge project in June 2025. The second post was about the possible hybrid cooling technology to be used at the site. Now, the project is facing some serious issues that may render it unable to be developed as planned.

     Fermi Inc., the startup co-founded by former Texas governor and Energy Secretary Rick Perry, went public in a transaction that allowed the company to raise nearly $746 million. By mid-April, things were looking different as Fermi’s stock price plunged about 84%, peaking at about $37 but trading at more than $5 a share this week. That is a huge loss. Energy writer Robert Bryce referred to Fermi’s fate as going from “sizzle to fizzle.” He explained that the losses reported by the company were not a good sign:

“On March 30, the company reported its 2025 financial results, and they were ugly. Fermi reported a full-year loss of $486.4 million, which included some $177.8 million in general and administrative expenses, $173.8 million in charitable expenses, $132.7 million in share-based compensation, and $111.6 million in losses related to financing,”

     Fermi is also being sued by at least one prospective tenant.

     In Mid-April, just six months or so after going public in the U.S. and London, the company announced that Toby Neugebauer, the co-founder and CEO, “departed his role as Chief Executive Officer.” The IPO valued Fermi at nearly $12.5 billion. However, since March 30, when the loss was announced, Fermi insiders have sold $68 million worth of the company’s stock. Bryce asks - If they are selling, why should others buy? He also notes that those stock sales raise other questions. He wonders whether they knew the CEO was leaving, which would not bode well for the stock price. In fact, the stock price dropped considerably after the CEO’s departure was announced. Since then, the company’s CFO, Miles Everson, resigned. He had also sold about $4 million in stock.

     In an April 24 Substack post, Bryce reports on the expensive private jetting of CEO Neugebauer, which he compares to Enron before that company imploded. On April 21, as Bryce reports:

“Neugebauer issued a press release in which he said the company’s board fired him “without cause.” The release said that Neugebauer “ultimately cares about making money for all shareholders more than finishing” what he started. Toward that end, he called on the Fermi board to “conduct an immediate process, led by an independent investment bank, for the sale of the Company to a third party.”

“Why would Neugebauer want a sale? I’m speculating here, but a quick sale might, repeat, might, allow Neugebauer and his family, who own about 40% of the company’s stock worth some $1.4 billion, to cash out without collapsing Fermi’s market capitalization. A few hours after Neugebauer’s press release was published, the company’s board issued its own press release confirming that Neugebauer had been fired. It rejected his call for a quick sale, saying it “firmly believes a sale is not in the best interest of its continued momentum on Project Matador.”

“While those events are noteworthy, the real bombshell dropped on Monday, when Fuzzy Panda Research, a short-seller, issued a savage takedown of Fermi that contains several allegations of misconduct by Neugebauer. The real blockbuster, though, is about Neugebauer and — you guessed it — a very expensive private jet.”

     He gave more details, but those were behind a paywall. In any case, it looks generally bad for the company and the project. While it may be revived, it seems unlikely that it will be developed fully and in a timely manner.

     According to a May 5 article in Barron’s, also behind a paywall, Fermi’s apparent “showdown with its former CEO took another twist after the ousted co-founder called for a shareholder meeting to decide whether to put the data-center developer up for sale.”

     Reuters reports that shareholders have rejected Neugebauer’s call for a special shareholders' meeting. The article summarizes recent events below.

      While I am not sure of all the details, this seems to be a case of high-flying, wealth-saturated, power-hungry individuals simply trying to get richer, and as Bryce suggests, reminiscent of Enron. 

     Electric power analyst Bill Peackock writes that if the project fails or is scaled down, it could affect power grid planning in Texas, where demand for power is very high, and the quest to ensure reliability in both winter and summer is often challenging. 

 

References:

 

Fermi Stock Slides as Ex-CEO Calls a Special Meeting. Will Shareholders Vote to Sell? Nate Wolf. Barron’s. May 05, 2026. Fermi Stock Slides as Ex-CEO Calls Special Meeting. Will Shareholders Vote to Sell? - Barron's

Are Fermi and Rick Perry in trouble in Amarillo? Oklahoma Energy Today. April 15, 2026. Are Fermi and Rick Perry in trouble in Amarillo? - Oklahoma Energy Today

Fermi Air: The high-flying hijinks of former Fermi CEO Toby Neugebauer. Robert Bryce. Substack, April 24, 2026. Fermi Air - Robert Bryce

Fermi Isn’t Faltering, It’s Imploding: Friday's departure of CEO Toby Neugebauer shows Fermi is in deep trouble. Robert Bryce. Substack. April 19, 2026. Fermi Isn’t Faltering, It’s Imploding - Robert Bryce

Fermi Troubles: A Warning for the Texas Grid. Bill Peacock. Master Resource. April 23, 2026. Fermi Troubles: A Warning for the Texas Grid - Master Resource

Fermi rejects ousted CEO's call for special shareholder meeting. Reuters. May 5, 2026. Fermi rejects ousted CEO's call for special shareholder meeting