Japan still buying Ukraine carbon permits

By Reuters


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Japan has no objection to buying more carbon emissions rights from Ukraine as its checks have shown that money Tokyo previously paid for permits has been properly accounted for, a government official said.

Ukraine's current government has accused the former prime minister of misusing the funds.

"We sent people to Ukraine twice last year and in November confirmed the full amount of money was secured at the account," So, we don't see any problem," the official said.

Developed nations which are comfortably below greenhouse gas targets under the Kyoto Protocol can sell excess emission rights to other countries, called Assigned Amount Units AAUs.

The AAU deal for 30 million tonnes of carbon dioxide equivalent was made in 2009 with Ukraine's former government headed by Yulia Tymoshenko. The payments were to be used for emissions cuts and other environment projects.

Ukraine's government has accused Tymoshenko of misusing 380 million euros US $499 million from the sale of AAUs, under a broader criminal investigation into the affairs of her government.

Tymoshenko denies charges of misusing state funds raised by selling carbon emission permits.

Ukraine's President Viktor Yanukovich is set to visit Japan. His agenda is expected to include selling more AAUs but the Japanese government official said Kiev has not officially made a new offer of AAUs to Japan.

The official said that Japan may not buy more emissions rights from Ukraine immediately as its last purchase, from Poland, moved it close to its target for 2008-2012.

Japan's government and companies have been the biggest buyers of Kyoto carbon rights outside Europe, aiming to help the world's fifth-biggest emitter meet its obligations to cut greenhouse gas emissions to 1.19 billion tonnes on average over Kyoto's 2008-2012 period, down 6 percent from 1990 levels.

A carbon trader in Tokyo said hardly any Japanese companies were interested in buying AAUs from Ukraine after the questions raised by the allegations of misuse.

"A negative image has attached to Ukraine's AAUs. I doubt there is ample demand to balance off the reputation risk," the trader said, adding that most of the major Kyoto carbon credit buyers, like power companies, have already bought as many credits as they needed for the 2008-2012 period.

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German official says nuclear would do little to solve gas issue

Germany Nuclear Phase-Out drives policy amid gas supply risks, Nord Stream 1 shutdown fears, Russia dependency, and energy security planning, as Robert Habeck rejects extending reactors, favoring coal backup, storage, and EU diversification strategies.

 

Key Points

Ending Germany's last reactors by year end despite gas risks, prioritizing storage, coal backup, and EU diversification.

✅ Reactors' legal certification expires at year end

✅ Minimal gas savings from extending nuclear capacity

✅ Nord Stream 1 cuts amplify energy security risks

 

Germany’s vice-chancellor has defended the government’s commitment to ending the use of nuclear power at the end of this year, amid fears that Russia may halt natural gas supplies entirely.

Vice-Chancellor Robert Habeck, who is also the economy and climate minister and is responsible for energy, argued that keeping the few remaining reactors running would do little to address the problems caused by a possible natural gas shortfall.

“Nuclear power doesn’t help us there at all,” Habeck, said at a news conference in Vienna on Tuesday. “We have a heating problem or an industry problem, but not an electricity problem – at least not generally throughout the country.”

The main gas pipeline from Russia to Germany shut down for annual maintenance on Monday, as Berlin grew concerned that Moscow may not resume the flow of gas as scheduled.

The Nord Stream 1 pipeline, Germany’s main source of Russian gas, is scheduled to be out of action until July 21 for routine work that the operator says includes “testing of mechanical elements and automation systems”.

But German officials are suspicious of Russia’s intentions, particularly after Russia’s Gazprom last month reduced the gas flow through Nord Stream 1 by 60 percent.

Gazprom cited technical problems involving a gas turbine powering a compressor station that partner Siemens Energy sent to Canada for overhaul.

Germany’s main opposition party has called repeatedly to extend nuclear power by keeping the country’s last three nuclear reactors online after the end of December. There is some sympathy for that position in the ranks of the pro-business Free Democrats, the smallest party in Chancellor Olaf Scholz’s governing coalition.

In this year’s first quarter, nuclear energy accounted for 6 percent of Germany’s electricity generation and natural gas for 13 percent, both significantly lower than a year earlier. Germany has been getting about 35 percent of its gas from Russia.

Habeck said the legal certification for the remaining reactors expires at the end of the year and they would have to be treated thereafter as effectively new nuclear plants, complete with safety considerations and the likely “very small advantage” in terms of saving gas would not outweigh the complications.

Fuel for the reactors also would have to be procured and Scholz has said that the fuel rods are generally imported from Russia.

Opposition politicians have argued that Habeck’s environmentalist Green party, which has long strongly supported the nuclear phase-out, is opposing keeping reactors online for ideological reasons, even as some float a U-turn on the nuclear phaseout in response to the energy crisis.

Reducing dependency on Russia
Germany and the rest of Europe are scrambling to fill the gas storage in time for the northern hemisphere winter, even as Europe is losing nuclear power at a critical moment and reduce their dependence on Russian energy imports.

Prior to the Russian invasion of Ukraine, Berlin had said it considered nuclear energy dangerous and in January objected to European Union proposals that would let the technology remain part of the bloc’s plans for a climate-friendly future that includes a nuclear option for climate change pathway.

“We consider nuclear technology to be dangerous,” government spokesman Steffen Hebestreit told reporters in Berlin, noting that the question of what to do with radioactive waste that will last for thousands of generations remains unresolved.

While neighbouring France aimed to modernise existing reactors, Germany stayed on course to switch off its remaining three nuclear power plants at the end of this year and phase out coal by 2030.

Last month, Germany’s economy minister said the country would limit the use of natural gas for electricity production and make a temporary recourse to coal generation to conserve gas.

“It’s bitter but indispensable for reducing gas consumption,” Robert Habeck said.

 

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Abengoa, Acciona to start work on 110MW Cerro Dominador CSP plant in Chile

Cerro Dominador CSP Plant delivers 110MW concentrated solar power in Chile's Atacama Desert, with 10,600 heliostats, 17.5-hour molten salt storage, and 24/7 dispatchable energy; built by Acciona and Abengoa within a 210MW complex.

 

Key Points

A 110MW CSP solar-thermal plant in Chile with heliostats and 17.5h molten salt storage, delivering 24/7 dispatchable clean power.

✅ 110MW CSP with 17.5h molten salt for 24/7 dispatch

✅ 10,600 heliostats; part of a 210MW hybrid CSP+PV complex

✅ Built by Acciona and Abengoa; first of its kind in LatAm

 

A consortium formed by Spanish groups Abengoa and Acciona, as Spain's renewable sector expands with Enel's 90MW wind build activity, has signed a contract to complete the construction of the 110MW Cerro Dominador concentrated solar power (CSP) plant in Chile.

The consortium received notice to proceed to build the solar-thermal plant, which is part of the 210MW Cerro Dominador solar complex.

Under the contract, Acciona, which has 51% stake in the consortium and recently launched a 280 MW Alberta wind farm, will be responsible for building the plant while Abengoa will act as the technological partner.

Expected to be the first of its kind in Latin America upon completion, the plant is owned by Cerro Dominador, which in turn is owned by funds managed by EIG Global Energy Partners.

The project will add to a Abengoa-built 100MW PV plant, comparable to California solar projects in scope, which was commissioned in February 2018, to form a 210MW combined CSP and PV complex.

Spread across an area of 146 hectares, the project will feature 10,600 heliostats and will have capacity to generate clean and dispatachable energy for 24 hours a day using its 17.5 hours of molten salt storage technology, a field complemented by battery storage advances.

Expected to prevent 640,000 tons of CO2 emission, the plant is located in the commune of María Elena, in the Atacama Desert, in the Antofagasta Region.

“In total, the complex will avoid 870,000 tons of carbon dioxide emissions into the atmosphere every year and, in parallel with Enel's 450 MW U.S. wind operations, will deliver clean energy through 15-year energy purchase agreements with distribution companies, signed in 2014.

“The construction of the solarthermal plant of Cerro Dominador will have an important impact on local development, with the creation of more than 1,000 jobs in the area during its construction peak, and that will be priority for the neighbors of the communes of the region,” Acciona said in a statement.

The Cerro Dominador plant represents Acciona’s fifth solar thermal plant being built outside of Spain. The firm has constructed 10 solarthermal plants with total installed capacity of 624MW.

Acciona has been operating in Chile since 1993. The company, through its Infrastructure division, executed various construction projects for highways, hospitals, hydroelectric plants and infrastructures for the mining sector.

 

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Trump's Proposal to Control Ukraine's Nuclear Plants Sparks Controversy

US Control of Ukraine Nuclear Plants sparks debate over ZNPP, Zaporizhzhia, sovereignty, safety, ownership, and international cooperation, as Washington touts utility expertise, investment, and modernization to protect critical energy infrastructure amid conflict.

 

Key Points

US management proposal for Ukraine's nuclear assets, notably ZNPP, balancing sovereignty, safety, and investment.

✅ Ukraine retains ownership; any transfer requires parliament approval.

✅ ZNPP safety risks persist amid occupation near active conflict.

✅ International reactions split: sovereignty vs. cooperation and investment.

 

In a recent phone call with Ukrainian President Volodymyr Zelenskyy, U.S. President Donald Trump proposed that the United States take control of Ukraine's nuclear power plants, including the Zaporizhzhia Nuclear Power Plant (ZNPP), which has been under Russian occupation since early in the war and where Russia is reportedly building power lines to reactivate the plant amid ongoing tensions. Trump suggested that American ownership of these plants could be the best protection for their infrastructure, a proposal that has sparked controversy in policy circles, and that the U.S. could assist in running them with its electricity and utility expertise.

Ukrainian Response

President Zelenskyy promptly addressed Trump's proposal, stating that while the conversation focused on the ZNPP, the issue of ownership was not discussed. He emphasized that all of Ukraine's nuclear power plants belong to the Ukrainian people and that any transfer of ownership would require parliamentary approval . Zelenskyy clarified that while the U.S. could invest in and help modernize the ZNPP, ownership would remain with Ukraine.

Security Concerns

The ZNPP, Europe's largest nuclear facility, has been non-operational since its occupation by Russian forces in 2022. The plant's location near active conflict zones raises significant safety risks that the IAEA has warned of in connection with attacks on Ukraine's power grids, and its future remains uncertain. Ukrainian officials have expressed concerns about potential Russian provocations, such as explosions, especially after UN inspectors reported mines at the Zaporizhzhia plant near key facilities, if and when Ukraine attempts to regain control of the plant.

International Reactions

The proposal has elicited mixed reactions both within Ukraine and internationally. Some Ukrainian officials view it as an opportunistic move by the U.S. to gain control over critical infrastructure, while others see it as a potential avenue for modernization and investment, alongside expanding wind power that is harder to destroy in wartime. The international community remains divided on the issue, with some supporting Ukraine's sovereignty over its nuclear assets and others advocating for a possible agreement on power plant attacks to ensure the plant's safety and future operation.

President Trump's proposal to have the U.S. take control of Ukraine's nuclear power plants has sparked significant controversy. While the U.S. offers expertise and investment, Ukraine maintains that ownership of its nuclear assets is a matter of national sovereignty, even as it has resumed electricity exports to bolster its economy. The situation underscores the complex interplay between security, sovereignty, and international cooperation in conflict zones.

 

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GM president: Electric cars won't go mainstream until we fix these problems

Electric Vehicle Adoption Barriers include range anxiety, charging infrastructure, and cost parity; consumer demand, tax credits, lithium-ion batteries, and performance benefits are accelerating EV uptake, pushing SUVs and self-driving tech toward mainstream mobility.

 

Key Points

They are the key hurdles to mainstream EV uptake: range anxiety, sparse charging networks, and high upfront costs.

✅ Range targets of 300+ miles reduce anxiety and match ICE convenience

✅ Expanded home, work, and public charging speeds adoption

✅ Falling battery costs and incentives drive price parity

 

The automotive industry is hurtling toward a future that will change transportation the same way electricity changed how we light the world. Electric and self-driving vehicles will alter the automotive landscape forever — it's only a question of how soon, and whether the age of electric cars arrives ahead of schedule.

Like any revolution, this one will be created by market demand.
Beyond the environmental benefit, electric vehicle owners enjoy the performance, quiet operation, robust acceleration, style and interior space. And EV owners like not having to buy gasoline. We believe the majority of these customers will stay loyal to electric cars, and U.S. EV sales are soaring into 2024 as this loyalty grows.

But what about non-EV owners? Will they want to buy electric, and is it time to buy an electric car for them yet? About 25 years ago, when we first considered getting into the electric vehicle business with a small car that had about 70 miles of range, the answer was no. But today, the results are far more encouraging.

We recently held consumer clinics in Los Angeles and Chicago and presented people with six SUV choices: three gasoline and three electric. When we asked for their first choice to purchase, 40% of the Chicago respondents chose an electric SUV, and 45% in LA did the same. This is despite a several thousand-dollar premium on the price of the electric models, and despite that EV sales still lag gas cars nationally today, consumer interest was strong (but also before crucial government tax credits that we believe will continue to drive people toward electric vehicles and help fuel market demand).

They had concerns, to be sure. Most people said they want vehicles that can match gasoline-powered vehicles in range, ease of ownership and cost. The sooner we can break down these three critical barriers, the sooner electric cars will become mainstream.

Range
Range is the single biggest barrier to EV acceptance. Just as demand for gas mileage doesn't go down when there are more gas stations, demand for better range won't ease even as charging infrastructure improves. People will still want to drive as long as possible between charges.

Most consumers surveyed during our clinics said they want at least 300 miles of range. And if you look at the market today, which is driven by early adapters, electric cars have hit an inflection point in demand, and the numbers bear that out. The vast majority of electric vehicles sold — almost 90% — are six models with the highest range of 238 miles or more — three Tesla models, the Chevrolet Bolt EV, the Hyundai Kona and the Kia Niro, according to IHS Markit data.

Lithium-ion batteries, which power virtually all electric cars on the road today, are rapidly improving, increasing range with each generation. At GM, we recently announced that our 2020 Chevrolet Bolt EV will have a range of 259 miles, a 21-mile improvement over the previous model. Range will continue to improve across the industry, and range anxiety will dissipate.

Charging infrastructure
Our research also shows that, among those who have considered buying an electric vehicle, but haven't, the lack of charging stations is the number one reason why.

For EVs to gain widespread acceptance, manufacturers, charging companies, industry groups and governments at all levels must work together to make public charging available in as many locations as possible. For example, we are seeing increased partnership activity between manufacturers and charging station companies, as well as construction companies that build large infrastructure projects, as the American EV boom approaches, with the goal of adding thousands of additional public charging stations in the United States.

Private charging stations are just as important. Nearly 80% of electric vehicle owners charge their vehicles at home, and almost 15% at work, with the rest at public stations, our research shows. Therefore, continuing to make charging easy and seamless is vital. To that end, more partnerships with companies that will install the chargers in consumers' homes conveniently and affordably will be a boon for both buyers and sellers.

Cost
Another benefit to EV ownership is a lower cost of operation. Most EV owners report that their average cost of operation is about one-third of what a gasoline-powered car owner pays. But the purchase price is typically significantly higher, and that's where we should see change as each generation of battery technology improves efficiency and reduces cost.

Looking forward, we think electric vehicle propulsion systems will achieve cost parity with internal combustion engines within a decade or sooner, and will only get better after that, driving sticker prices down and widening the appeal to the average consumer. That will be driven by a number of factors, including improvements with each generation of batteries and vehicles, as well as expected increased regulatory costs on gasoline and diesel engines.

Removing these barriers will lead to what I consider the ultimate key to widespread EV adoption — the emergence of the EV as a consumer's primary vehicle — not a single-purpose or secondary vehicle. That will happen when we as an industry are able to offer the utility, cost parity and convenience of today's internal combustion-based cars and trucks.

To get the electric vehicle to first-string status, manufacturers simply must make it as good or better than the cars, trucks and crossovers most people are used to driving today. And we must deliver on our promise of making affordable, appealing EVs in the widest range of sizes and body styles possible. When we do that, electric vehicle adoption and acceptance will be widespread, and it can happen sooner than most people think.

Mark Reuss is president of GM. The opinions expressed in this commentary are his own.

 

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UK's Energy Transition Stalled by Supply Delays

UK Clean Energy Supply Chain Delays are slowing decarbonization as transformer lead times, grid infrastructure bottlenecks, and battery storage contractors raise costs and risk 2030 targets despite manufacturing expansions by Siemens Energy and GE Vernova.

 

Key Points

Labor and equipment bottlenecks delay transformers and grid upgrades, risking the UK's 2030 clean power target.

✅ Transformer lead times doubled or tripled, raising project costs

✅ Grid infrastructure and battery storage contractors in short supply

✅ Firms expand capacity cautiously amid uncertain demand signals

 

The United Kingdom's ambitious plans to transition to clean energy are encountering significant obstacles due to prolonged delays in obtaining essential equipment such as transformers and other electrical components. These supply chain challenges are impeding the nation's progress toward decarbonizing its power sector by 2030, even as wind leads the power mix in key periods.

Supply Chain Challenges

The global surge in demand for renewable energy infrastructure, including large-scale storage solutions, has led to extended lead times for critical components. For example, Statera Energy's storage plant in Thurrock experienced a 16-month delay for transformers from Siemens Energy. Such delays threaten the UK's goal to decarbonize power supplies by 2030.

Economic Implications

These supply chain constraints have doubled or tripled lead times over the past decade, resulting in increased costs and straining the energy transition as wind became the main source of UK electricity in a recent milestone. Despite efforts to expand manufacturing capacity by companies like GE Vernova, Hitachi Energy, and Siemens Energy, the sector remains cautious about overinvesting without predictable demand, and setbacks at Hinkley Point C have reinforced concerns about delivery risks.

Workforce and Manufacturing Capacity

Additionally, there is a limited number of companies capable of constructing and maintaining battery sites, adding to the challenges. These issues underscore the necessity for new factories and a trained workforce to support the electrification plans and meet the 2030 targets.

Government Initiatives

In response to these challenges, the UK government is exploring various strategies to bolster domestic manufacturing capabilities and streamline supply chains while supporting grid reform efforts underway to improve system resilience. Investments in infrastructure and workforce development are being considered to mitigate the impact of global supply chain disruptions and advance the UK's green industrial revolution for next-generation reactors.

The UK's energy transition is at a critical juncture, with supply chain delays posing substantial risks to achieving decarbonization goals, including the planned end of coal power after 142 years for the UK. Addressing these challenges will require coordinated efforts between the government, industry stakeholders, and international partners to ensure a sustainable and timely shift to clean energy.

 

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B.C. ordered to pay $10M for denying Squamish power project

Greengen Misfeasance Ruling details a B.C. Supreme Court decision awarding $10.125 million over wrongfully denied Crown land and water licence permits for a Fries Creek run-of-river hydro project under a BC Hydro contract.

 

Key Points

A B.C. Supreme Court ruling awarding $10.125M for wrongful denial of Crown land and water licences on Greengen's project.

✅ $10.125M damages for misfeasance in public office

✅ Denial of Crown land tenure and water licence permits

✅ Tied to Fries Creek run-of-river and BC Hydro EPA

 

A B.C. Supreme Court judge has ordered the provincial government to pay $10.125 million after it denied permits to a company that wanted to build a run-of-the river independent power project near Squamish.

In his Oct. 10 decision, Justice Kevin Loo said the plaintiff, Greengen Holdings Ltd., “lost an opportunity to achieve a completed and profitable hydro-electric project” after government representatives wrongfully exercised their legal authority, a transgression described in the ruling as “misfeasance,” with separate concerns reflected in an Ontario market gaming investigation reported elsewhere.

Between 2003 and 2009, the company sought to develop a hydro-electric project on and around Fries Creek, which sits opposite the Brackendale neighbourhood on the other side of the Squamish River. To do so, Greengen Holdings Ltd. required a water licence from the Minister of the Environment and tenure over Crown land from the Minister of Agriculture.

After a lengthy process involving extensive communications between Greengen and various provincial and other ministries and regulatory agencies, the permits were denied, according to Loo. Both decisions cited impacts on Squamish Nation cultural sites that could not be mitigated.

Elsewhere, an Indigenous-owned project in James Bay proceeded despite repeated denials, underscoring varied approaches to community participation.

40-year electricity plan relied on Crown land
The case dates back to December 2005, when BC Hydro issued an open call for power with Greengen. The company submitted a tender several months later.

On July 26, 2006, BC Hydro awarded Greengen an energy purchase agreement, amid evolving LNG electricity demand across the province, under which Greengen would be entitled to supply electricity at a fixed price for 40 years.

Unlike conventional hydroelectric projects, such as new BC generating stations recently commissioned, which store large volumes of water in reservoirs, and in so doing flood large tracts of land, a run of the river project often requires little or no water storage. Instead, from a high elevation, they divert water from a stream or river channel.

Water is then sent into a pressured pipeline known as a penstock, and later passed through turbines to generate electricity, Loo explained, as utilities pursue long-term plans like the Hydro-Québec strategy to reduce fossil fuel reliance. The system returns water to the original stream or river, or into another body of water. 

The project called for most of that infrastructure to be built on Crown land, according to the ruling.

All sides seemed to support the project
In early 2005, company principle Terry Sonderhoff discussed the Fries Creek project in a preliminary meeting with Squamish Nation Chief Ian Campbell.

“Mr. Sonderhoff testified that Chief Campbell seemed supportive of the project at the time,” Loo said.

 

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