Palestinian Authority joins power pact

China 2060 Carbon-Neutral Energy Transition projects tripled electricity, rapid electrification, wind and solar dominance, scalable hydrogen, CCUS, and higher carbon pricing to meet net-zero goals while decarbonizing heavy industry and transport.

Key Points

Shell's outlook for China to reach net zero by 2060 via electrification, renewables, hydrogen, CCUS, and carbon pricing.

✅ Power supply to 60% of energy; generation triples by 2060.

✅ Wind and solar reach 80% of electricity; coal declines sharply.

✅ Hydrogen scales to 17 EJ; CCUS and carbon pricing expand.

China may triple electricity generation to supply 60 percent of the country's total energy under Beijing's carbon-neutral goal by 2060, up from the current 23 per cent, according to Royal Dutch Shell.

Shell is one of the largest global investors in China's energy sector, with business covering gas production, petrochemicals and a retail fuel network. A leading supplier of liquefied natural gas, it has recently expanded into low-carbon business such as hydrogen power and electric vehicle charging.

In a rare assessment of the country's energy sector by an international oil major, Shell said China needed to take quick action this decade to stay on track to reach the carbon-neutrality goal.

China has mapped out plans to reach peak emissions by 2030, and aims to reduce coal power production over the coming years, but has not yet revealed any detailed carbon roadmap for 2060.

This includes investing in a reliable and renewable power system, including compressed air generation, and demonstrating technologies that transform heavy industry using hydrogen, biofuel and carbon capture and utilization.

"With early and systematic action, China can deliver better environmental and social outcomes for its citizens while being a force for good in the global fight against climate change," Mallika Ishwaran, chief economist of Shell International, told a webinar hosted by the company's China business.

Shell expects China's electricity generation to rise three-fold to more than 60 exajoules (EJ) in 2060 from 20 EJ in 2020, even amid power supply challenges reported recently.

Solar and wind power are expected to surpass coal as the largest sources of electricity by 2034 in China, reflecting projections that renewables will eclipse coal globally by mid-decade, versus the current 10 percent, rising to 80 percent by 2060, Shell said.

Hydrogen is expected to scale up to 17 EJ, or equivalent to 580 million tonnes of coal by 2060, up from almost negligible currently, adding over 85 percent of the hydrogen will be produced through electrolysis, supported by PEM hydrogen R&D across the sector, powered by renewable and nuclear electricity, Shell said.

Hydrogen will meet 16 percent of total energy use in 2060 with heavy industry and long-distance transport as top hydrogen users, the firm added.

The firm also expects China's carbon price to rise to 1,300 yuan (CDN$256.36) per tonne in 2060 from 300 yuan in 2030.

Nuclear, on a steady development track, and biomass will have niche but important roles for power generation in the years to come, Shell said.

Electricity generated from biomass, combined with carbon, capture, utilization and storage (CCUS), provide a source of negative emissions for the rest of the energy system from 2053, it added.

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SM-1A Nuclear Plant Decommissioning details the US Army Corps of Engineers' removal of the Fort Greely reactor, Cold War facility dismantling, environmental monitoring, remote-site power history, and timeline to 2026 under a deactivated nuclear program.

Key Points

Army Corps plan to dismantle Fort Greely's SM-1A reactor and complete decommissioning of remaining systems by 2026.

✅ Built for remote Arctic radar support during the Cold War

✅ High costs beat diesel; program later deemed impractical

✅ Reactor parts removed; residuals monitored; removal by 2026

The US Army Corps of Engineers has begun decommissioning Alaska’s only nuclear power plant, SM-1A, which is located at Fort Greely, even as new US reactors continue to take shape nationwide. The $17m plant closed in 1972 after ten years of sporadic operation. It was out of commission from 1967 to 1969 for extensive repairs. Much of has already been dismantled and sent for disposal, and the rest, which is encased in concrete, is now to be removed.

The plant was built as part of an experimental programme to determine whether nuclear facilities, akin to next-generation nuclear concepts, could be built and operated at remote sites more cheaply than diesel-fuelled plants.

"The main approach was to reduce significant fuel-transportation costs by having a nuclear reactor that could operate for long terms, a concept echoed in the NuScale SMR safety evaluation process, with just one nuclear core," Brian Hearty said. Hearty manages the Army Corps of Engineers’ Deactivated Nuclear Power Plant Program.

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He said the Army built SM-1A in 1962 hoping to provide power reliably at remote Arctic radar sites, where in similarly isolated regions today new US coal plants may still be considered, intended to detect incoming missiles from the Soviet Union at the height of the Cold War. He added that the programme worked but not as well as Pentagon officials had hoped. While SM-1A could be built and operated in a cold and remote location, its upfront costs were much higher than anticipated, and it costs more to maintain than a diesel power plant. Moreover, the programme became irrelevant because of advances in Soviet rocket science and the development of intercontinental ballistic missiles.

Hearty said the reactor was partially dismantled soon after it was shut down. “All of the fuel in the reactor core was removed and shipped back to the Atomic Energy Commission (AEC) for them to either reprocess or dispose of,” he noted. “The highly activated control and absorber rods were also removed and shipped back to the AEC.”

The SM-1A plant produced 1.8MWe and 20MWt, including steam, which was used to heat the post. Because that part of the system was still needed, Army officials removed most of the nuclear-power system and linked the heat and steam components to a diesel-fired boiler. However, several parts of the nuclear system remained, including the reactor pressure vessel and reactor coolant pumps. “Those were either kept in place, or they were cut off and laid down in the tall vapour-containment building there,” Hearty said. “And then they were grouted and concreted in place.” The Corps of Engineers wants to remove all that remains of the plant, but it is as yet unclear whether that will be feasible.

Meanwhile, monitoring for radioactivity around the facility shows that it remains at acceptable levels. “It would be safe to say there’s no threat to human health in the environment,” said Brenda Barber, project manager for the decommissioning. Work is still in its early stages and is due to be completed in 2026 at the earliest. Barber said the Corps awarded the $4.6m contract in December to a Virginia-based firm to develop a long-range plan for the project, similar in scope to large reactor refurbishment efforts elsewhere. Among other things, this will help officials determine how much of the SM-1A will remain after it’s decommissioned. “There will still be buildings there,” she said. “There will still be components of some of the old structure there that may likely remain.”

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Labrador Island Link Reliability faces scrutiny as Nalcor Energy and General Electric address software issues; Liberty Consulting warns of Holyrood risks, winter outages, grid stability concerns, and PUB oversight for Newfoundland and Labrador.

Key Points

It is the expected dependability of the link this winter, currently uncertain due to GE software and Holyrood risks.

✅ GE software delays may hinder reliable in-service by mid-November.

✅ Holyrood performance issues increase winter outage risk.

✅ PUB directs Hydro to plan contingencies and improve assets.

An independent consultant is questioning if the brand new Labrador Island link can be counted on to supply power to Newfoundland this coming winter.

In June, Nalcor Energy confirmed it had successfully sent power from Churchill Falls to the Avalon Peninsula through its more than 1500-kilometre link, but now the Liberty Consulting Group says it doesn't expect the link will be up and running consistently this winter.

"What we have learned supports a conclusion that the Labrador Island Link is unlikely to be reliably in commercial operation at the start of the winter," says the report dated Aug. 30, 2018.

The link relies on software provided by General Electric but Liberty says there are lingering questions about GE's ability to ensure the necessary software will be in place this fall.

"At an August meeting, company representatives did not express confidence in GE's ability to meet an in-service date for the Labrador Island Link of mid-November," says the report.

Liberty also says testing the link for a brief period this spring and fall doesn't demonstrate long-term reliability.

"The link will remain prone to the uncertainties any new major facility faces early in its operating life, especially one involving technology new to the operating company," according to the report.

Holyrood trouble

The report goes on to say island residents should also be worried about the reliability of the troubled Holyrood facility — a facility that's important when demand for energy is high during winter months.

Liberty says "poor performance at the Holyrood thermal generating station increases the risk of outages considerably."

The group's report concludes the deteriorating condition of Holyrood is a major threat to the island's power supply and Liberty says that threat "could produce very severe consequences when the Labrador Island Link is unavailable."

The consultant says questions about the Labrador Island Link's readiness combined with concerns about the reliability of Holyrood may mean power outages, and for vulnerable customers, debates over hydro disconnections policies often intensify during winter.

"This all suggests that, for at least part of this winter, the island interconnected system may be at the mercy of the weather, where severe events can test utilities' storm response efforts further."

The consultant's report also includes five recommendations to the PUB, reflecting the kind of focused nuclear alert investigation follow-up seen elsewhere.

In essence, Liberty is calling for the board to direct Newfoundland and Labrador Hydro to make plans for the possibility that the link won't be available this winter. It's also calling on hydro to do more to improve the reliability of its other assets, such as Holyrood, as some operators have even contemplated locking down key staff to maintain operations during crises.

Response to Liberty's report

Nalcor CEO Stan Marshall defended the Crown corporation's winter preparedness in an email statement to CBC.

"The right level of planning and investment has been made for our existing equipment so we can continue to meet all of our customer electricity needs for this coming winter season," he wrote.

Regarding the Labrador Island Link, Marshall called for patience.

"This is new technology for our province and integrating the new transmission assets into our current electricity system is complex work that takes time," he said.

There is also a more detailed response from Newfoundland and Labrador Hydro which was sent to the province's Public Utiltiies Board.

Hydro says it will keep testing the Labrador Island Link and increasing the megawatts that are wheeled through it. It also says in October it will begin to give the PUB regular reports on the link's anticipated in-service date.

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Sunrun-Tesla Virtual Power Plant Texas leverages residential solar, Tesla Powerwall battery storage, and ERCOT demand response to enhance grid resilience, cut emissions, and supply backup power via a coordinated distributed energy resources network.

Key Points

A Texas VPP using residential solar and Tesla Powerwall to aid ERCOT with grid services resilience, and less emissions.

✅ Aggregates Powerwall storage for ERCOT demand response.

✅ Enhances grid reliability with distributed energy resources.

✅ Cuts emissions by shifting solar to peak and outage periods.

In a significant development for renewable energy and grid resilience, Sunrun and Tesla have announced a groundbreaking partnership to establish a distributed power plant in Texas. This collaboration represents a major step forward in harnessing solar energy and battery storage, with advances in affordable solar batteries helping to create a more reliable and sustainable power system. The initiative aims to address the growing demand for clean energy solutions while enhancing grid stability and resilience in one of the largest and most energy-dependent states in the U.S.

The new distributed power plant, a joint venture between Sunrun, a leading residential solar provider, and Tesla, renowned for its advanced battery technology and electric vehicles, will leverage the strengths of both companies to transform how energy is generated and used. The project will deploy Tesla's Powerwall battery systems alongside Sunrun's solar panels to create a network of interconnected residential energy storage units. This network will function as a virtual power plant, aligned with emerging peer-to-peer energy sharing models that are capable of providing electricity back to the grid during periods of high demand or outages.

Texas, with its vast and growing population, has faced significant energy challenges in recent years. The state’s power grid, managed by the Electric Reliability Council of Texas (ERCOT), has experienced strain during extreme weather events and high demand periods, and instances of Texas wind curtailment during grid stress, leading to concerns about reliability and stability. The partnership between Sunrun and Tesla seeks to address these concerns by introducing a more flexible and resilient energy solution.

The distributed power plant will consist of thousands of residential solar installations, each equipped with Tesla Powerwall batteries, reflecting the broader trend of pairing storage with solar across the U.S. as it scales. These batteries store excess solar energy generated during the day and release it when needed, such as during peak demand times or power outages. By connecting these systems through advanced software, the project will create a coordinated network of distributed energy resources that can respond dynamically to fluctuations in energy supply and demand.

One of the key benefits of this distributed approach is its ability to enhance grid reliability. Traditional power plants are centralized and can be vulnerable to disruptions, whether from extreme weather, technical failures, or other issues. In contrast, a distributed power plant spreads the generation and storage capacity across numerous locations, a principle echoed by renewable power developers pursuing multi-resource projects today, reducing the risk of widespread outages and increasing the overall resilience of the power grid.

Additionally, the project will contribute to the reduction of greenhouse gas emissions. By increasing the use of solar energy and reducing reliance on fossil fuels, and amid ongoing work to improve solar and wind technologies, the distributed power plant supports Texas’s climate goals and contributes to broader efforts to combat climate change. The integration of renewable energy sources into the grid helps to decrease carbon emissions and promote a cleaner, more sustainable energy system.

The partnership between Sunrun and Tesla also underscores the growing role of technology in transforming the energy landscape. Tesla's Powerwall battery systems represent some of the most advanced energy storage technology available, and amid record solar and storage growth nationwide this decade they showcase the capability to store and manage energy efficiently. Sunrun’s expertise in residential solar installations complements this technology, creating a powerful combination that leverages the latest advancements in clean energy.

The project is expected to deliver several benefits to both individual homeowners and the broader community. Homeowners who participate in the program will have access to solar energy and battery storage at reduced costs, thanks to the economies of scale and innovative financing options provided by Sunrun and Tesla. Additionally, they will have the added security of backup power during outages, contributing to greater energy independence and resilience.

For the broader community, the distributed power plant offers a more reliable and sustainable energy system. The ability to generate and store energy at the residential level reduces the strain on traditional power plants and enhances the overall stability of the grid. Furthermore, the project will contribute to local job creation, as the installation and maintenance of solar panels and battery systems require skilled workers.

As the project moves forward, Sunrun and Tesla will work closely with local stakeholders, regulators, and utility providers to ensure the successful implementation and integration of the distributed power plant. Collaboration with these parties will be essential to addressing any regulatory, technical, or logistical challenges and ensuring that the project delivers its intended benefits.

In conclusion, the partnership between Sunrun and Tesla to create a distributed power plant in Texas represents a significant advancement in clean energy technology and grid resilience. By combining solar power with advanced battery storage, the project aims to enhance grid stability, reduce emissions, and provide reliable energy solutions for homeowners. As Texas continues to face energy challenges, this innovative initiative offers a promising model for the future of distributed energy and highlights the potential for technology-driven solutions to address pressing environmental and infrastructure issues.

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China Nuclear Power Expansion accelerates with reactor approvals, Hualong One and CAP1400 deployments, rising gigawatts, clean energy targets, carbon neutrality goals, and grid reliability benefits to meet coastal demand and reduce emissions.

Key Points

An accelerated reactor buildout to add clean capacity, curb emissions, and improve grid reliability nationwide.

✅ Approvals surge for Hualong One and CAP1400 third-gen reactors

✅ Capacity targets approach 100 GW installed by 2030

✅ Supports carbon neutrality, energy security, and lower costs

While China has failed to accomplish its 2020 nuclear target of 58 gigawatts under operation and 30 GW under construction, insiders are optimistic about prospects for the nonpolluting energy resource in China over the next five years as the country has stepped up nuclear approvals and construction since 2020.

China expects to record 49 operating nuclear facilities and capacity of more than 51 GW as of the end of 2020. Nuclear power currently makes up around 2.4 percent of the country's total installed energy capacity, said the China Nuclear Energy Association. There are 19 facilities that have received approval and are under construction, with capacity exceeding 20 GW, ranking top globally as nuclear project milestones worldwide continue, it said.

"With surging power demand from coastal regions, more domestic technology, including next-gen nuclear, will be adopted with installations likely nearing 100 GW by the end of 2030," said Wei Hanyang, a power market analyst at Bloomberg New Energy.

Following the Fukushima nuclear reactor disaster in 2011 in Japan, China has, like many countries including Japan, Germany and Switzerland, suspended nuclear power project approvals for a period, including construction of the pilot project of Shidaowan nuclear power plant in Shandong province that uses CAP1400 technology, based on third-generation Westinghouse AP1000 reactor technology.

As China promotes greener development and prioritizes safety and security of nuclear power plant construction, it has pledged to hit peak emissions before 2030 and achieve carbon neutrality by 2060, with electricity meeting 60% of energy use by 2060 according to Shell, the Shidaowan plant, originally scheduled to launch construction in 2014 and enter service in 2018, is expected to start fuel loading and begin operations this year.

Joseph Jacobelli, an independent energy analyst and executive vice-president for Asia business at Cenfura Ltd, a smart energy services company, said recent developments confirm China's ongoing commitment to further boost the country's nuclear sector.

"The nuclear plants can help meet China's goal of reducing greenhouse gas emissions as the country reduces coal power production and provide air pollution-free energy at a lower cost to consumers. China's need for clean energy means that nuclear power generation definitely has an important place in the long-term energy mix," Jacobelli said.

He added that Chinese companies' cost control capabilities and technological advancements, and operational performance improvements such as the AP1000 refueling outage record, are also likely to continue providing domestic companies with advantages, as the cost per kilowatt-hour is very important, especially as solar, wind and other clean energy solutions become even cheaper over the next few years.

China approved two nuclear projects in 2020- Hainan Changjiang nuclear power plant unit 2 and Zhejiang San'ao nuclear power plant unit 1. This is after the country launched three new nuclear power plants in 2019 in the provinces of Shandong, Fujian and Guangdong, which marked the end of a moratorium on new projects.

The Zhejiang San'ao nuclear power plant saw concrete poured for unit 1 on Dec 31, according to its operator China General Nuclear. It will be the first of six Hualong One pressurized water reactors to be built at the site as well as the first Chinese nuclear power plant project to involve private capital.

Jointly invested, constructed and operated by CGN, Zheneng Electric Power, Wenzhou Nuclear Energy Development, Cangnan County Haixi Construction Development and Geely Maijie Investment, the project creates a new model of mixed ownership of nuclear power enterprises, said CGN.

The world's first Hualong One reactor at unit 5 of China National Nuclear Corp's Fuqing nuclear plant in Fujian province was connected to the grid in November. With the start of work on San'ao unit 1, China now has further seven Hualong One units under construction, including Fuqing 6, which is scheduled to go online this year.

CNNC is also constructing one unit at Taipingling in Guangdong and two at Zhangzhou in Fujian province. CGN is building two at its Fangchenggang site in Guangxi Zhuang autonomous region. In addition, two Hualong One units are under construction at Karachi in Pakistan, while CGN proposes to use a UK version of the Hualong One at Bradwell in the United Kingdom, aligning with the country's green industrial revolution strategy.

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Canada Oil and Gas Emissions Cap sets five-year targets to cut sector emissions toward net-zero by 2050, alongside an EV mandate, carbon pricing signals, and support for carbon capture, clean energy jobs, climate policy.

Key Points

A federal policy to regulate and reduce oil and gas emissions via 5-year targets, reaching net-zero by 2050.

✅ Regulated 5-year milestones to cut oil and gas emissions to net-zero by 2050

✅ Interim EV mandate: 50% by 2030; 100% zero-emission sales by 2035

✅ $2B fund for clean energy jobs in oil- and gas-reliant communities

Liberal Leader Justin Trudeau vowed to regulate total emissions from Canada’s oil and gas producers as he laid out his first major climate change promises of the campaign Sunday, a plan that was welcomed by several environmental and climate organizations.

Trudeau said that if re-elected, the Liberals will set out regulated five-year targets for emissions from oil and gas production to get them to net-zero emissions by 2050, a goal that, according to an IEA report will require more electricity, but also create a $2 billion fund to create jobs in oil and gas-reliant communities in Alberta, Saskatchewan and Newfoundland and Labrador.

“Let’s be realistic, over a quarter of Canada’s emissions come from our oil and gas sector. We need the leadership of these industries to decarbonize our country,” Trudeau said.

“That’s why we’ll make sure oil and gas emissions don’t increase and instead go down with achievable milestones,” while ensuring local economies can prosper.“

The Liberals are also introducing an interim electric vehicle mandate, which will require half the cars sold in Canada to be zero-emission by 2030, and because cleaning up electricity is critical to meeting climate pledges, the policy pairs with power-sector decarbonization, ahead of the final mandated target of 100 per cent by 2035.

Trudeau spoke in Cambridge, Ont., where protesters once again made an appearance amid a visible police presence. Officers carried one woman off the property when she refused to leave when asked.

Trudeau alluded to the protesters and their actions, which included sounding sirens and chanting expletives, as he defended his government’s record on climate change including progress in the electricity sector nationally, and touted its new plan.

“Sirens in the background may remind us that this is a climate emergency. That’s why we will move faster and be bolder,” he said.

Canada’s largest oilsands producers have already committed to reaching net zero greenhouse gas emissions by 2050, but the policy proposed Sunday “calls the oil companies’ bluff” by making those goals a legislated requirement, said Keith Stewart, senior energy strategist with Greenpeace Canada.

The new timeline for electric vehicles also “sends a clear signal to auto companies to get cracking (and build them here),” he said on Twitter, even as proposals like a fully renewable grid by 2030 are debated today. “We’d like to see this happen faster but the shift away from voluntary targets to requirements is big.”

Merran Smith, executive director of Clean Energy Canada, a climate program at Simon Fraser University, said clean electricity, clean transportation and “phasing out oil and gas with accountable milestones” must be key priorities over the next decade, aligning with Canada’s race to net-zero and the role of renewable energy.

“Today’s announcement, which checks all of these boxes, is not just good ambition_it’s good policy. Policy that will drive down carbon pollution and drive up clean job growth and economic competitiveness. It is policy that will drive Canada forward with cleaner cars, power Canada with clean electricity, and invest in businesses that will last such as battery manufacturing, electric vehicle manufacturing and low carbon steel,” Smith said in an email.

Michael Bernstein, executive director of the climate policy organization Clean Prosperity, said the promises laid out Sunday offer a “strong boost” to the federal government’s previous climate commitments.

He said the organization prefers market incentives such as carbon pricing, that spur innovation over further regulation. But since the largest oilsands companies have already committed to reaching net-zero emissions, he said the newly unveiled policy could provide some support.

“ First, I would encourage the Liberal Party to release independent modelling showing the types of emissions reductions they expect to achieve with their new package of policies. Second, many policies are referred to in general terms so I hope the Liberal Party will provide further details in the coming days,” he said.

“Finally, the document does not specifically mention carbon capture or carbon dioxide removal technologies but both technologies will be critical to achieve some of the pledges in today’s announcement, especially reaching net-zero emissions in the oil a gas sector.”

NDP Leader Jagmeet Singh painted the announcement as the latest in a string of “empty promises” from the Liberals on climate change, saying Canada has the highest increase in greenhouse gas emissions among all G7 countries, and that provinces like B.C. risk missing 2050 targets as well, he argued.

“Climate targets mean nothing when you don’t act on them. We can’t afford more of Justin Trudeau’s empty words on climate change,” he said in a statement.

The Trudeau Liberals submitted new targets to the United Nations in July, promising that Canada will curb emissions by 40 to 45 per cent from 2005 levels by 2030, building on the net-zero by 2050 plan announced earlier, officials say.

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