Sunday, April 12, 2026

 

Canada's labour market is 'static' after a year of U.S. tariffs, population shift



Published: 26 

Workers inspect sheets of stainless steel after being pressed from coils, at Magna Stainless and Aluminum in Montreal on Thursday, Sept. 18, 2025. THE CANADIAN PRESS/Christopher Katsarov

OTTAWA — Thursday marks one year since U.S. President Donald Trump upended the global trading system with his “Liberation Day” duties — a major step in his wider tariff campaign that’s hammered critical sectors of Canada’s labour market.

With roughly a year of employment data now in hand showing the impact of Trump’s tariffs on Canadian jobs, economists say some of the early resilience to the trade disruption is giving way to a stalled labour market. A shrinking labour pool is also throttling job growth, experts warn.

And there are now risks that weakness could be spilling over from industries hard-hit by tariffs into services and sectors not directly exposed to the new trading order.

“The labour market over the past year has been pretty stable, and maybe even a better word for that is static,” said Brendon Bernard, senior economist at job search platform Indeed.

While the particular Liberation Day tariffs were recently ruled illegal by the U.S. Supreme Court, the impact started even earlier for Canada, with threats in February that materialized into sector-specific tariffs in March that are still in effect.

Statistics Canada’s latest labour force survey for February shows the winners of losers after a year of tariffs.

Manufacturing, a sector targeted directly by steep U.S. tariffs on steel, aluminum and autos, has shed 51,800 jobs over the previous 12 months, leading all industries for losses. The bulk of those lost jobs were in manufacturing-heavy Ontario.

Andrew DiCapua, principal economist at the Canadian Chamber of Commerce, said he is worried the pain isn’t over for the automotive industry.

Work contracts in this sector are often set over six- or 12-month periods, he said. That could mean a further “recalibration” is coming for this part of the labour market as those contracts roll off the books.

Statistics Canada said in March that the industrial capacity utilization rate — how much Canadian industries are collectively producing compared with their potential — was 78.5 per cent in the fourth quarter of last year, down modestly from the previous quarter.

“If companies are not able to produce at these high levels, well, then they don’t need the workers to fulfill orders. So I just fear that the momentum and the weakness may continue,” DiCapua said.

Desjardins senior economist Kari Norman said the impact of tariffs has been steep on an individual and sectoral basis for many Canadian workers, but the hit to the national labour market has so far not been as bad as initially feared.

Norman said the outlook for manufacturing is highly dependent on the upcoming review of the Canada-U.S.-Mexico trade agreement later this year.

If Canada exits that review with a firm commitment and tariff levels similar to where they stand today, Norman said she thinks “we’ll continue to see manufacturing level off, rather than decline in terms of employment.”

StatCan’s labour force survey shows goods-producing sectors have collectively lost 34,200 positions year-over-year as of February, though services industries have more than offset those losses with a gain of 85,900 positions.

Canada’s health-care sector led those gains, adding 92,000 jobs over the past year. Norman said that makes sense as provinces continue to invest in health staffing to care for an aging population.

Strength in the services sector has been one reason Canada’s unemployment rate hasn’t deteriorated sharply over the past year.

But there were signs in February of cracks in that resilience: StatCan reported an 84,000-job loss in the month, led by a contraction in services.

When there’s prolonged weakness on one side of the labour market — say, because of a rapid tariff-driven drop-off in export demand — it can spread to the other side of the economy.

DiCapua gave the example of an auto parts worker in southwest Ontario losing a regular shift, and therefore not getting a Tim Hortons coffee on the way into work. After a while, Tim Hortons might decide it also doesn’t need as many staff to meet dwindling demand and could eventually pull back on advertising too, spurring knock-on effects through the economy.

DiCapua noted that provinces seeing the hardest hits from U.S. duties such as Ontario, Quebec, and British Columbia are also seeing less growth in services.

“I don’t want to draw too many conclusions on that other than to say that there could be just this general ... weaker sentiment (around) U.S. tariffs and it could be affecting sectors that are maybe not directly affected,” he said.

Bernard said it’s “not surprising” that U.S. tariffs combined with a sharply slowing housing market are leading to spillover effects in Ontario’s labour market.

Some economists also view the steep job losses in February with a grain of salt.

While the monthly labour force survey is well-known among economists for its volatility, the less timely survey of employment, payrolls and hours — the SEPH — offers a different perspective of the jobs market.

Bernard said when the labour force survey was reporting a surge of job growth in the fourth quarter of last year, the SEPH was flat. That could suggest a more stable trend than the up-and-down monthly job headlines imply.

But whichever data source Canadians prefer to look at, Bernard said one thing is clear over the past year.

“Job growth by both metrics absolutely slowed down,” he said.

“The main driver of that, though, is what’s going on with population growth and demographics.”

StatCan reported in March that the Canadian population shrank in 2025, the first year on record with an outright decline.

With a growing number of baby boomers hitting retirement age and fewer young workers coming into replace them, Bernard noted that the size of the labour force will likely be flat or even decline in the coming months.

He said that means Canada needs to add fewer jobs to keep the unemployment rate steady. Monthly employment declines would also be more commonplace in the more volatile labour force survey, he argued.

“When the trend is flat ... it’s going to be bouncing around that flat number,” Bernard said.

“Even absent the economy shifting, this is going to happen more.”

Desjardins’ outlook has the unemployment rate for 2026 holding around 6.7 per cent — right in line with February’s figures — before improving next year.

Norman said that status-quo forecast might come with a few pockets of job gains, with projected increases in government spending on defence and construction likely to spur hiring in those fields.

She also suggested that high levels of youth unemployment might come down in the summer jobs season as an energy price spike tied to the Iran war sends jet fuel and airfare costs soaring. That could push more Canadian families to vacation closer to home this year, she said.

“That should help support the tourism sector in Canada and those youth jobs that correspond to that,” she said.

This report by The Canadian Press was first published April 2, 2026.

Craig Lord, The Canadian Press

Alberta says it’s sitting on a potential US$1 trillion lithium resource: What happens now?

ByAnam Khan
Published: April 02, 2026 


Brine sampling in progress at LithiumBank’s owned Leduc Formation well in West-Central Alberta. (LithiumBank)

Alberta is sitting on one of the largest lithium resources in the world. The challenge now is proving it can actually be produced.

The province’s rich lithium discovery is not sudden.

Scientists and oil companies knew of dissolved lithium in underground brine across oil and gas fields for decades, according to Alberta’s Ministry of Energy and Minerals, but the economics and technology were not in place to measure it or extract it.

Until recently.

Last week, the province quantified its in-place lithium resources for the first time. The Alberta Geological Survey found Alberta holds 82.5 million tonnes of lithium carbonate equivalent, potentially ranking it as the third largest lithium resource in the world.


“Times have changed,” says the ministry pointing to rising demand for lithium in electric vehicles, batteries, data centres and consumer electronics.

On paper, the resource could be worth nearly US$1 trillion if produced using direct lithium extraction, a technology companies like E3 Lithium have been racing to perfect.

E3 Lithium’s 2023 DLE field pilot plant in Alberta. The plant successfully demonstrated the ability to produce battery-grade lithium concentrate from brine, supporting the transition toward commercial-scale production in Western Canada. (Photo: E3 Lithium)

The company’s CEO, Chris Doornbos cautioned the figure is theoretical, noting “you never get 100 per cent” of the value in the ground, but the report is significant.

“I think the validation is here now,” said Doornbos.

“We’ve needed more and more lithium. It’s most of what’s coming out of China today, but the big push from the G7 countries to go domestic so quickly is probably the biggest, most important moment.”

Doornbos said the shift is not about discovering lithium, but about extracting it economically, which could allow Canada to build its own battery supply chain.

“We are in deficit in the North American battery ecosystem,” he said.Canada is racing to refine this key battery ingredient at home
How companies plan to make it work

E3 Lithium has spent years developing technology to extract lithium from brine in Alberta’s Leduc reservoir, a byproduct of oil and gas operations previously considered wastewater.

The company began developing its technology in 2016, piloted it in 2023 and launched a demonstration facility in 2025.

“We’re going to see the technology prove out… demonstrating it to people who will finance this project,” said Doornbos.

“That for us commercializes lithium.”

E3 is targeting first production between 2028 and 2029, with an initial output of about 12,000 tonnes annually. Doornbos said securing financing remains one of the biggest hurdles.

E3 Lithium’s Demonstration Facility, commissioned in September 2025, has produced battery-grade lithium carbonate since its launch. Equipment is now being relocated to a new site as the company prepares to begin large-scale operations. (Photo: E3 Lithium)

Other Alberta-based companies are taking a different approach. LithiumBank is working with a major oilfield services company to scale extraction.

Alberta’s lithium is lower grade than the brines found in South America, making extraction more complex, but Alberta’s vast resource base and existing oil and gas infrastructure help offset that, says the chief operating officer of LithiumBank, Kevin Piepgrass.

“We have dozens of wells that we can potentially reuse. We have pipelines that we can reuse, roads, power lines… all these things in place that really reduces the capex,” he said.

Piepgrass said direct lithium extraction is not optional in Alberta.

“The only way it’s possible… is direct lithium extraction,” he said, noting the province cannot rely on evaporation methods used in warmer climates.

LithiumBank is targeting initial production of about 10,000 tonnes per year, with potential to scale up to 34,000 tonnes. Piepgrass said the company could see first production around 2030 if development moves ahead as planned.

Unlike some global producers that ship lithium abroad for processing, Alberta projects aim to produce battery-grade lithium domestically.
Big opportunity, but real risks remain

The reason lithium is an attractive opportunity for Canada is because it builds on Alberta’s oil and gas workforce, says John Kirton, a professor at the University of Toronto and director of the G7 Research Group.

He said lithium could “make Alberta genuinely a clean energy superpower.”

“It’s highly attractive for producing what’s called a just transition,” he said, noting oil and gas workers could transition into lithium development.

Kirton said the discovery is significant because Canada currently imports lithium largely from the United States, while exporting much of its own output south.

But he warned there are major uncertainties, like technology.

“It is still unproven at commercial scale,” he said.

He also pointed to Canada’s lack of processing capacity, noting the country is “not meaningfully in the lithium processing game,” which could require further investment.

Global competition is another challenge. Established producers like Chile and Argentina have proven extraction methods and favourable climates.

At the same time, lithium prices remain volatile. “It can just crash,” Kirton said, adding that “there’s a new technology… sodium works even better and is cheaper.”

He says while small to medium businesses may benefit from the domestic supply chains, the economic payoff for Canada as a whole could take about a decade.
Governments are betting on it

Lithium is already a priority under Canada’s Critical Minerals Strategy, with billions committed to building domestic supply chains.

Doornbos said part of that push is driven by concerns over global market dynamics, including China’s dominance in the sector.

E3 Lithium has received about $80 million in combined federal and provincial funding, while LithiumBank has received support from Alberta and is in discussions with the federal government.

Natural Resources of Canada currently ranks Canada as the sixth leading lithium producer in the world.

The department says it will update the ranking after Alberta’s recent geological report.

Anam Khan

Journalist, BNNBloomberg.ca

World Nuclear News


Three US states pave way for new nuclear



Legislation lifting a long-standing nuclear moratorium has been signed in New Jersey; legislation to incentivise nuclear construction has been signed in Kentucky; and in Texas, applications have opened for USD350 million of funding appropriated by the state to boost advanced nuclear construction.
 

Governor Mikie Sherrill signs the New Jersey legislation at the Salem nuclear power plant (Image: Office of Governor/Tim Larsen)

New Jersey Governor Mikie Sherrill signed the legislation to remove the permitting hurdle that has created a de facto moratorium and announced the launch of the state's new Nuclear Task Force after a tour of PSEG's Salem nuclear power plant.

"For costs to come down, we need more energy supply. New Jersey is well-positioned to be a leader in next-generation nuclear energy to help bring that supply, and we are open for business," Sherrill said. "By lifting outdated barriers and bringing together leaders across government, industry, and labour, we're setting the stage for our state to pursue new advanced nuclear power. This will help New Jersey secure a stronger, cleaner, more affordable, and reliable energy future - while keeping the state at the forefront of innovation, job creation, and economic growth."

A nuclear moratorium is a state-imposed ban or restriction on building new nuclear capacity, but how this looks varies from state to state: for example, a state might set conditions related to legislative approvals, voter consent, or waste disposal requirements before construction can begin. According to the US Nuclear Energy Institute, eight US states - California, Hawaii, Maine, Massachusetts, Minnesota, Oregon, Rhode Island and Vermont - have long-standing nuclear moratoriums. Connecticut has partially lifted its moratorium, and while New York conditionally lifted its moratorium many years ago a specific moratorium remains in parts of Long Island.

New Jersey's Coastal Area Facility Review Act blocks new permits for the construction and operation of new nuclear energy facilities by requiring an approved method by the Nuclear Regulatory Commission (NRC) for radioactive waste disposal, which New Jersey says is an outdated standard that cannot be met. The new legislation - S3870/A4528 - resolves the issue by allowing the commissioner of New Jersey's Department of Environmental Protection to approve permits that are "based on safe, NRC-compliant waste storage", removing the de facto moratorium and clearing the path for new nuclear energy development.

The newly formed Nuclear Task Force, co-chaired by Elizabeth Noll, Senior Strategist for Energy at the Office of the Governor, and Christine Guhl-Sadovy, President of the New Jersey Board of Public Utilities, will be organised across five focus areas - Financing, Supply Chains and Technology Development, Workforce Growth and Training, Regulatory and Permitting Framework, and Public Trust and Confidence - with the goal of ensuring that New Jersey is "ready to capture the benefits of new nuclear power, while maintaining the highest standards of public safety and transparency."

Two nuclear power plants - the two-unit Salem and the single-unit Hope Creek, all owned by PSEG - currently provide around 42% of New Jersey's electricity.

Kentucky incentives

Legislation signed by Governor Andy Beshear on 8 April establishes the Kentucky Nuclear Energy Development Authority and, under it, the Nuclear Reactor Site Readiness Pilot Program "to facilitate the application for and procurement of early site permits, construction permits, or combined operating licences from the NRC for the siting of new nuclear energy generating facilities".

Beshear said Senate Bill 57 would potentially lead to lower utility rates for Kentuckians over the long term. "Every step makes a difference when it comes to helping our people save their hard-earned dollars," he said.

Kentucky does not currently have any nuclear generation capacity.

Texas funding

Texas has issued a request for applications for USD350 million of funding appropriated to the Texas Advanced Nuclear Development Fund (TANDF). Applications are being accepted for the TANDF's Advanced Nuclear Construction Reimbursement Program and Project Design and Supply Chain Reimbursement Program.

The fund is under the Texas Advanced Nuclear Energy Office (TANEO), which was established by the Texas legislature to provide strategic leadership for the advanced nuclear industry and associated supply chain industries in Texas and to promote the development of advanced nuclear reactors in the state, amongst other things.

Eligible applicants must be businesses, nonprofit organisations, and governmental entities, including institutions of higher education "that have - or reasonably expect to have - a docketed construction permit or licence application for the project at the NRC on or before 1 December 2026". Applications are due by mid-May.

Production begins at US uranium project


Uranium Energy Corp's Burke Hollow in Texas is the first new in-situ recovery operation to start up in the USA in over a decade.
 
Burke Hollow (Image: CNW Group/Uranium Energy Corp)

In-situ recovery - or ISR - is a method of mining uranium by dissolving and recovering it via wells. It is also known as in-situ leaching. Ground water fortified with a complexing agent, and often with an oxidant (such as gaseous oxygen), is introduced into the orebody to dissolve the uranium from the sandstone host. The uranium-bearing before being recovered and processed into yellowcake.

Uranium Energy Corp (UEC) has two ISR hub and spoke platforms in South Texas and Wyoming, with a central processing plant as the "hub" with several ISR uranium projects providing "spokes". Production from Burke Hollow will be processed at the company's Hobson Central Processing Plant, which is licensed to produce up to 4 million pounds of uranium per year.

"The startup of Burke Hollow is a significant achievement for UEC, advancing the project from a grassroots discovery in 2012 to production in 2026," UEC President and CEO Amir Adnani said. "With two ISR operations now producing, and our Ludeman ISR project planned for startup in 2027, we are building a scalable, multi-faceted platform supported by the largest uranium resource base in the United States."

According to UEC, Burke Hollow is the largest ISR uranium discovery in the USA in the past decade, with significant long-term development potential: only about half of the property, which covers some 20,000 acres (over 8,000 hectares) has been explored to date. The estimated mineral resource for the project is currently 6,155,000 pounds U3O8 (2,368 tU) in the measured and indicated category, plus 4,883,000 pounds U3O8 of inferred resources.

Production was able to start following the receipt of final approvals from the Texas Commission on Environmental Quality (TCEQ). Craig Wall, UEC's Vice President, Environmental, Health & Safety, Texas said the commission's approval, coming after more than a decade of exploration, permitting and development, "reflects the strength of our technical and operational execution. We appreciate the collaboration and professionalism of the TCEQ throughout the process and look forward to continuing to work with them as the project advances."

UEC's South Texas team will now focus on ramping operations and constructing additional wellfields across the project.

In addition to the largest uranium resource base in the USA, with 12 million pounds per year of uranium production capacity across its Wyoming and South Texas hub-and-spoke ISR operations, UEC also controls extensive land and resource portfolios in Canada's Athabasca Basin, including the Roughrider Project in Saskatchewan. The company is also pursuing domestic refining and conversion capabilities in the USA through its United States Uranium Refining & Conversion Corp subsidiary.

New Korean reactor cleared for start up


South Korea's Nuclear Safety and Security Commission said it has completed all nine inspections required to be performed prior to the reactor's initial criticality during the pre-operation inspection of Saeul unit 3.
 
Saeul 3 (Image: KHNP)

In January 2014, the government authorised construction of two APR1400 units as Saeul units 3 and 4 (formerly known as Shin Kori 5 and 6). Construction was originally scheduled to start in September 2014, but was then delayed. The regulator issued a construction licence in June 2016, and site works began immediately. Construction of unit 3 commenced in April 2017. However, following the change in government in June 2017, Korea Hydro & Nuclear Power (KHNP) decided to suspend work for three months. In October 2017, a government-organised committee voted 59.5% in favour of resuming construction of the two units. The committee stated that stability of power supply had been cited as a primary reason for the choice in survey responses. In September 2018, construction of unit 4 commenced.

Prior to the delay, commercial operation of the units was due in March 2021 and March 2022, respectively. In late December 2025 the Nuclear Safety and Security Commission (NSSC) issued an operating licence for Saeul 3, with fuel loading and approximately eight months of testing to follow. Commercial operation is expected around August 2026. Saeul 4 is expected to follow in late 2026.

"Since the operating licence was issued last year, the NSSC has been conducting pre-operational inspections (5 stages) on Saeul unit 3," the regulator said. "During this process, inspections were conducted on items that must be performed before criticality, such as nuclear fuel loading inspections and high-temperature functional tests. As a result, it was confirmed that reactor criticality can be safely achieved."

The NSSC said it plans to finally confirm the safety of the unit by conducting follow-up inspections, including power increase tests, from the time Saeul 3 achieves first criticality - a sustained chain reaction - until it enters commercial operation.

Once commercially operational, Saeul 3 will account for about 1.7% of South Korea's total power generation and 37% of Ulsan's electricity demand.

South Korea has four operational APR1400 units - Saeul units 1 and 2 (formerly Shin Kori 3 and 4) and Shin Hanul units 1 and 2, plus the APR1400s under construction as Saeul units 3 and 4. Four APR1400 units have also been built at the Barakah nuclear power plant in the UAE, which are all now in commercial operation.

Dismantling of reactor channels to begin at second Ignalina unit


With the dismantling of the reactor channels of unit 1 at Lithuania's Ignalina nuclear power plant complete, the country's nuclear regulator has now issued a permit for dismantling and decontamination works on the upper and lower zone equipment of the reactor channels of unit 2.
 
(Image: Altra)

In accordance with the approved technical design, the steam-water discharge piping at the top of the reactor and the water supply piping at the bottom of the reactor, as well as other related systems and their components, will be dismantled, and initial treatment of radioactive waste will be carried out. The project also includes the dismantling of the fuel channels and the reactor control and safety channels located within the reactor.

Altra - the Lithuanian state-owned company leading the decommissioning of the Ignalina plant - said dismantling work is scheduled to begin at the end of 2026. Until then, the company will carry out preparatory work: installation of engineering systems, testing of remote control equipment, and upgrading and adaption of the radioactive waste management infrastructure to handle the waste generated during this project.

"The dismantling of the reactor channels of the first power unit has been completed, therefore the permit for the second unit paves the way for a consistent continuation of the dismantling process of both reactors," Altra said.


(Image: Altra)

"Nobody in the world has ever dismantled a power plant of this size and radiation contamination," said Altra CEO Linas Baužys. "The transition to the second unit is a significant step forward in implementing the mega-project for decommissioning the Ignalina nuclear power plant. We have dismantled two-thirds of the first reactor with our own forces - the most complex and radiation-hazardous dismantling of the reactor cores remains, for which we will use external contractors. Our experience with the first unit allows us to confidently move on to the dismantling stages of the second unit. We are carrying out some of the work using remote and robotic technologies to ensure the highest safety standards."

The dismantling of unnecessary systems and equipment at the power plant has been carried out since 2010, and the overall dismantling progress has already reached 45.7%, Altra said. It is planned that the final dismantling of the reactors, including the dismantling of the most complex reactor cores, will take place by 2043, and all decommissioning-related work will be completed by 2050, with the final cleaning of the reactor buildings.

This year, Altra also plans to carry out dismantling and decontamination works on the steam drum separators of both power units of the Ignalina plant. There are eight such devices - metal cylinders with a diameter of almost 3 metres and a length of about 30 metres - in both power units of the plant, the total weight of which exceeds 6,000 tonnes. In November 2024, US-based company Amentum was awarded a contract worth an estimated EUR5.5 million (USD6.5 million) to consult for the first-of-a-kind dismantling of steam drum separators at Ignalina units 1 and 2.

Lithuania assumed ownership of the two RBMK-1500 units - light-water, graphite-moderated reactors, similar to those at Chernobyl - in 1991, after the collapse of the Soviet Union. It agreed to shut down the Ignalina plant as a condition of its accession to the European Union, with unit 1 shutting down in December 2004 and unit 2 in December 2009. The reactors are expected to be fully decommissioned by 2038, with most of the cost of the decommissioning being funded by the European Union via the European Bank for Reconstruction and Development and other funds.

ČEZ eyeing 80-year operation of Dukovany units


Czech energy group ČEZ announced it has started a preparatory process to enable the long-term operation of the four reactors at its Dukovany nuclear power plant. It is also considering extending the operation of the two reactors at its Temelín plant.
 
Dukovany (Image: CEZ)

ČEZ currently operates four VVER-440 units at Dukovany, which began operating between 1985 and 1987. Their output has gradually been increased from the original 440 MWe to 512 MWe through extensive modernisations. Ongoing modernisation work aims to ensure the units can operate for at least 60 years, to 2045-2047.

A CZK407 billion (USD19.6 billion) contract was signed with Korea Hydro & Nuclear Power last year for two of its APR1000 reactors near the existing Dukovany units. The aim is to start construction in 2029. Two more units at the Temelín plant are also being considered. There are also developing plans for small modular reactors in the country.

"We have planned to operate our nuclear power plants for about 60 years so far and we are convinced every day that they are in excellent condition," said ČEZ CEO Daniel Beneš. "Current economic and safety analyses confirm that it will be possible to operate Dukovany for longer. Eighty-year operation is becoming a trend in the world, and a number of units have already been licensed for 80 years of operation. We see this as realistic for us as well, provided of course that the condition of the equipment and the safety of operation are regularly evaluated. Of course, this will not affect the project to build a new nuclear power plant at Dukovany and other small modular reactors. Electricity consumption will grow rapidly, and the Czech Republic will need as much emission-free electricity as possible."

ČEZ said it regularly evaluates the future operation of its nuclear power plants using a technology and financial model, which assesses the technical condition of key components and the expected development of electricity prices and other inputs. "These analyses also indicate that the long-term operation of the Dukovany nuclear power plant is very well feasible," it said.

"Every year we evaluate the conditions for further operation in great detail, and all key decisions are supervised by the State Office for Nuclear Safety," said Bohdan Zronek, Director of ČEZ's nuclear energy division. "In ten-year cycles, our nuclear power plants undergo detailed and demanding 'periodic safety assessments'. Rigorous preparation and perfect knowledge of the condition of the plant is a prerequisite for any decision."

The company noted that 80 years of operation encompasses extensive capital projects and upgrade programmes. These include, for example, the renewal of some elements of the engine rooms - generators as well as other large units, the reconstruction of selected piping routes, valves and electrical elements as well as the gradual introduction of new control and safety systems.

ČEZ said the extended operation of the Dukovany plant "is a step that significantly strengthens the energy security of the Czech Republic and confirms ČEZ's long-term strategy as a stable and reliable supplier of low-emission electricity, even in times of dynamic changes on the energy market."

The company said analyses are now being carried out on the potential extension of the Temelín plant's operation. Two VVER-1000 units are in operation at Temelín, which came into operation in 2000 and 2002. The capacity of the two units has increased from the original 1,000 MWe per unit to 1,086 MWe.


(Image: Ministry of Industry and Trade)

At a press conference to announce the possible extension of the operation of the Dukovany units, Minister of Industry and Trade Karel Havlíček said: "We must decide on future energy sources at the same time as how long we can safely and effectively operate the existing ones, especially nuclear units. The operation of Dukovany for up to 80 years is not a replacement for new units, but their logical addition within the framework of the Czech energy strategy. The Czech Republic has extraordinary know-how in nuclear energy and we can operate our power plants safely, efficiently and with a high degree of reliability. Therefore, it makes sense to prepare for the long-term operation of Dukovany up to the 80-year mark. At the same time, however, this does not change the need to continue the construction of new nuclear sources and the preparation of small modular reactors, because the Czech Republic will need stable, safe and competitive electricity in the maximum possible volume."

Štěpán Kochánek, Chairman of the State Office for Nuclear Safety, added: "The service life of nuclear power plants in the Czech Republic is not strictly limited to a specific number of years. Simply put, it is governed by the condition of safety-relevant components. Extension of operation is possible only if the operator proves that the facility meets all safety requirements, has managed the aging management of the facility and the technical condition corresponds to current standards, and at the same time has the necessary personnel resources to ensure continued operation. We will always assess every step and every submitted assessment very strictly and in detail."

First criticality for Indian fast breeder reactor

The initiation of a controlled nuclear fission chain reaction at the Prototype Fast Breeder Reactor sees India move into the second stage of a three-stage nuclear programme which ultimately aims to achieve a closed fuel cycle using the country's abundant thorium.
 

Celebrating initial criticality at PFBR (Image: BHAVINI)

The 500 MWe Prototype Fast Breeder Reactor (PFBR) at Kalkpakkam in Tamil Nadu attained first criticality on 6 April at 08:25 pm, the Department of Atomic Energy (DAE) announced, with the milestone marking "a significant step toward strengthening India's long-term energy security and advancing its indigenous nuclear technology capabilities."

The PFBR technology was designed and developed by the DAE's Indira Gandhi Centre for Atomic Research (IGCAR). The reactor was built and commissioned by Bharatiya Nabhikiya Vidyut Nigam Ltd (BHAVINI), a government enterprise under the DAE. Construction began in 2004, with an original expected completion date of 2010. India's Atomic Energy Regulatory Board officially granted permission for the First Approach to Criticality - including the loading of fuel into the reactor core and the start of low power physics experiments - in mid-2024. Last August, Minister of State Jitendra Singh told India's parliament that delays in completion of the project had been mainly due to "first-of-a-kind technological issues" during the commissioning process.

The attainment of first criticality "follows the successful completion of all stipulated safety requirements, with clearance granted by the Atomic Energy Regulatory Board (AERB) after rigorous review," BHAVINI said.

"Today, India takes a defining step in its civil nuclear journey, advancing the second stage of its nuclear programme," Prime Minister Narendra Modi said on social media, adding that the PFBR "reflects the depth of our scientific capability and the strength of our engineering enterprise. It is a decisive step towards harnessing our vast thorium reserves in the third stage of the programme. A proud moment for India."

The PFBR uses uranium-plutonium mixed oxide, or MOX, fuel surrounded by a 'blanket' of uranium-238, which, through neutron absorption, is converted into fissile plutonium-239. This enables the reactor to generate more fuel than it consumes - it 'breeds' fuel. The PFBR is also designed to use thorium-232 in the blanket, which can be transmuted into fissile uranium-233.

"This unique capability significantly enhances the utilisation of nuclear fuel resources and enables the country to extract far greater energy from its limited uranium reserves while also preparing for large-scale use of thorium in the future," BHAVINI said. The fast breeder programme "strengthens strategic capabilities in nuclear fuel cycle technologies, advanced materials, reactor physics and large-scale engineering," and the knowledge and infrastructure developed through the programme "will support future reactor designs and next-generation nuclear technologies".

Fast breeder reactors form the second stage of India's three-stage nuclear programme, using plutonium recovered from the reprocessing of used fuel from the pressurised heavy water and light water reactors that form the first stage of the programme. The third stage envisages using advanced heavy water reactors to burn thorium-plutonium fuels and breed fissile uranium-233, achieving a thorium-based closed nuclear fuel cycle.

According to World Nuclear Association information, some 20 fast neutron reactors, including some that have supplied electricity commercially, have operated around the world since the 1950s - although not all have been breeders.

India currently has about 7,900 MW of nuclear generation from 24 operable nuclear power plants, and is planning a large expansion of its nuclear capacity. The country says that 17 nuclear power reactors with a total of 13,100 MW capacity are either under construction (7) or under pre-project activities (10). It is aiming to reach a nuclear energy capacity of about 100 GW by 2047 as part of its Viksit Bharat development strategy.

EDF, NTPC sign MoU to explore new Indian nuclear projects


The non-binding Memorandum of Understanding sees India's largest integrated power utility come together with the French international energy company to explore cooperation in developing new nuclear power projects in India.
 
(Image: NTPC)

The MoU was signed following approval from Indian ministries and government departments, NTPC said. It establishes a framework for both companies to jointly assess the feasibility and approach for collaboration, including understanding EDF’s EPR technology and its suitability for Indian requirements, exploring opportunities to maximise localisation for large-scale deployment, examining economic and tariff aspects, developing human resource capabilities through training programmes, evaluating potential project sites, and providing technical support as mutually agreed.

"This initiative aligns with NTPC’s strategy to expand into clean, reliable energy and contribute to India’s long-term energy security," NTPC said.

The MoU was signed by Arnada Prasad Samal, CGM (Nuclear Cell), on behalf of NTPC, and Vakisasi Ramany, Senior Vice President, International Nuclear Development, on behalf of EDF.

NTPC is a Public Sector Undertaking under India's Ministry of Power. It currently operates more than 89 GW of installed capacity, with another 32 GW under construction, with a target to reach 149 GW of total capacity by 2032, including 60 GW from renewable energy sources, with a balanced mix of thermal, hydro, solar, and wind power plants, ensuring supply of reliable, affordable, and sustainable electricity to the country.

Proposals for six EPR units at Jaitapur have long featured in India's energy plans, under the control of Nuclear Power Corporation of India Ltd (NPCIL).

Restrictions under Indian law have in the past presented a barrier to the participation of private companies like NTPC in nuclear power projects, but in 2024, the Indian government approved the creation of Anushakti Vidhyut Nigam Ltd (Ashvini), a joint venture between NPCIL and NTPC, to construct, own and operate nuclear power plants in India. The joint venture is now developing two Indian-designed 700 MWe pressurised heavy water reactors, Mahi Banswara Rajasthan Atomic Nuclear Power Project units 1 and 2, for which excavation works began in late March. The Sustainable Harnessing and Advancement of Nuclear Energy for Transforming India (SHANTI) Act 2025 - enacted at the end of last year - opens up India's nuclear sector to participation from private companies, including in plant operations, power generation, equipment manufacturing, and selected activities such as nuclear fuel fabrication.

Study highlights opportunities for Dutch nuclear supply chain



With the Dutch province of Zeeland under consideration as the location of two new nuclear power plants, a new report says local businesses could capture up to EUR4.6 billion (USD5.4 billion) in direct economic value during the 12-year construction period.
 
(Image: Impuls Zeeland)

The study - conducted by Tractebel and Technopolis and commissioned by the Province of Zeeland, Impuls Zeeland and VNO NCW Brabant Zeeland - outlines how companies in Zeeland, one of the preferred locations for new nuclear reactors, can position themselves within the nuclear supply chain and benefit from future investments.

Conducted between July 2025 and January 2026, the analysis explored prospects primarily for large nuclear new build projects, as well as for small modular reactors (SMRs) and the lifetime extension of the existing Borssele nuclear power plant.

The study identified 130 Zeeland businesses that could potentially supply nuclear projects, mostly as component suppliers and subcontractors. "Opportunities are strongest in construction, infrastructure, and transport & logistics, and during early construction phases and site clearance/landscaping," it says. "As a first estimate, local involvement could account for roughly 15% of total plant costs."

The direct economic potential for the business sector in Zeeland is estimated to be between EUR3.1 and EUR4.6 billion over a 12-year construction period. Direct economic benefits emerge from the direct supply to nuclear power plants, whether under construction or in operation. "The actual order size that can land in Zeeland will strongly depend on various factors, including the technology vendor chosen," the report says. "This estimate should therefore be considered a first estimate based on best available data and assumptions at this stage of the nuclear new-build project in the Netherlands." The indirect economic potential (resulting from regional spending of businesses directly involved in the supply chain and of on-site workers or visitors) for the business sector in Zeeland is estimated to be around EUR1 billion.

"Given the opportunities for Zeeland businesses in the nuclear supply chain, we recommend positioning Zeeland as a hotspot for nuclear energy and actively promoting its businesses in new-build projects," the study says." Stakeholders should be informed about nuclear developments, supply opportunities, and requirements, while businesses should be connected regionally, nationally, and internationally, and regional and national governments should align business support activities. Support should be provided to establish the right ecosystem for Zeeland companies to enter the nuclear domain, including further developing and implementing the proposed roadmap, backed by public and private investments.

"To facilitate this, we recommend establishing the Nuclear Delta platform, a public-private initiative bringing together businesses, government, and education institutions. The Province of Zeeland, Impuls Zeeland and VNO-NCW Brabant-Zeeland can play a part in this as well. Additionally, clear agreements with the national government should be made on conditions for hosting a new nuclear power plant, ensuring maximum economic benefit for regional businesses and reinforcing Zeeland’s ambitions as a nuclear energy hotspot."

The Netherlands currently has one 485 MWe (net) pressurised water reactor at Borssele - operated by EPZ - which has been in operation since 1973 and accounts for about 3% of the country's total electricity generation. 

In December 2021, the Netherlands' new coalition government placed nuclear power at the heart of its climate and energy policy. In addition to keeping the Borssele plant in operation for longer, the government also called for the construction of new reactors. Based on preliminary plans, two new reactors will be completed around 2035 and each will have a capacity of 1,000-1,650 MWe. The two reactors would provide 9-13% of the country's electricity production in 2035. The cabinet announced in December 2022 that it currently sees Borssele as the most suitable location for the construction of the new reactors. Three other locations are also being considered for the reactors: the Tweede Maasvlakte near Rotterdam, Terneuzen in Zeeland and Eemshaven in Groningen. A location selection is expected in September of this year. The government is also taking steps to prepare the Netherlands for the possible deployment of SMRs.


 

Global Energy Shortages Drive Renewed Reliance on Coal

  • Disruptions to oil and gas flows—especially through the Strait of Hormuz—are driving countries to fall back on coal as a fast, cheap energy source

  • Asia and parts of Europe are most exposed, with several nations increasing coal use despite prior commitments to reduce emissions

  • A sustained return to coal could significantly undermine global decarbonization efforts and delay the clean energy transition

Governments worldwide are racing to find a solution to contend with the severe energy shortages brought about by the war in Iran and the ongoing Middle East conflict. For some, this means accelerating the deployment of renewable energy, which is likely to be a longer-term solution. For others, it means relying on stockpiles of crude, while the oil trade remains limited. And, for many, it means using any type of energy available, including coal.

Several countries have reduced their reliance on coal in recent years in favour of oil, gas, and renewable energy sources. This has supported the beginnings of a global green transition, decreasing dependence on the highly polluting fossil fuel as the cost of the production of other energy sources, such as solar and wind energy, has fallen. However, due to energy shortages and rising fuel prices, many countries could come to rely on coal to meet their energy demand once again.

The U.S.-Israeli attack on Iran and the ongoing conflict in the Middle East have caused the biggest oil disruption in history, according to an analysis by consulting firm Rapidan Energy. A large proportion of the world’s oil supply has been disrupted for over a month, following the closure of the Strait of Hormuz – a key trade corridor connecting the Persian Gulf with the Gulf of Oman and the Arabian Sea. The strait is used to transport around 20 percent of the world’s oil when fully operational, but only a small fraction of that has passed through the waters in recent weeks.

While many governments release supplies of stockpiled crude and ask consumers and businesses to cut energy use, some are also discussing restarting coal plants to meet demand as they face energy shortages. Increasing coal production is seen as a relatively cheap and fast way to tackle the shortage and high price of oil and gas.

While several countries have decreased their reliance on gas, others have used the “dirtiest fossil fuel” to meet the growing consumer demand for energy, particularly in Southeast Asia. Global coal consumption has risen by around 1.3 billion tons since 2020, to 8.8 billion tons. This has been driven by countries such as China and India, as well as through geopolitical challenges, such as the Russian invasion of Ukraine, which led to the introduction of sanctions on Russian energy and drove Europe to stop buying Russian gas.

Even with world leaders being increasingly aware of the risks associated with coal production and use, many are still turning to the fuel when shortages arise, as the renewable energy capacity of most countries remains underdeveloped. With around 20 percent of the natural gas supply unable to move through the Strait of Hormuz, several countries in Asia and Europe are expected to increase their coal use.

Asia has been disproportionately affected by the shortages due to its heavy reliance on Middle Eastern countries for oil and gas. This has led Japan, India, Bangladesh, the Philippines, South Korea, Thailand, and Taiwan to increase their use of coal, or to consider doing so imminently. Indonesia, the world’s largest coal exporter, is currently prioritising domestic use over exports, which could contribute to tighter regional supplies and higher coal prices.

In South Korea, which has pledged to retire most coal plants by 2040 and halve its emissions by 2035, the government has been allowing most coal use when air pollution is low, a nd LNG is in short supply. The government has been forced to turn to coal at times due to the slow deployment of new renewable energy capacity, as green energy provides just 10 percent of the country’s electricity in 2024, compared to the global average of 32 percent.

Meanwhile, in Europe, where most countries have significantly reduced their coal production and usage, some countries anticipate having to use coal once again. The Italian government recently decided to postpone the closure of its coal-fired power plants for 13 years, to 2038, marking a U-turn from previous climate pledges. Meanwhile, Germany is deciding whether it will need to turn back on some of its idled coal plants. However, governments across Europe have yet to signal an imminent shift back to coal due to the Middle East conflict, suggesting that most will look for alternative solutions before returning to a reliance on coal, which would compromise their climate goals.

Nevertheless, if some countries around the globe are forced to shift reliance on coal once again, it could significantly hinder the global climate progress of recent years. Turning coal plants back on could undo much of the decarbonisation progress that has been achieved over the last decade and reduce the contribution of cleaner energy sources to the overall energy demand of several countries. 

By Felicity Bradstock for Oilprice.com

 

Central Asia’s Air Pollution Crisis Deepened Sharply in 2025

  • Tajikistan ranked third worst globally for air quality in 2025, while Uzbekistan placed 10th.

  • Pollution levels increased across all Central Asian states, with Tajikistan posting the biggest rise.

  • Only Azerbaijan showed slight improvement in the Caucasus, while global air quality also worsened overall.

Tajikistan and Uzbekistan are among the top 10 countries in the world with the poorest air quality, according to the findings published by a Swiss research firm. More broadly, Central Asia experienced a sharp increase in pollution in 2025.

According to IQAir’s World Air Quality Report for 2025, the air in Tajikistan contained an average of 57.3 micrograms of PM2.5 particles per cubic meter (µg/m³), an amount 11.5 times higher than the World Health Organization’s guidelines for acceptable air quality. Tajikistan’s general air quality ranked as the third worst in the world behind Pakistan and Bangladesh. The 2025 survey measured air quality in 143 countries around the globe.  

Uzbekistan ranked 10th in the 2025 survey with a PM2.5 concentration exceeding WHO guidelines by 7.6 times. Kyrgyzstan had the 19th-worst air quality, and Kazakhstan ranked 29th. Turkmenistan, which ranked 26th in 2024, was dropped from the latest list due to a lack of reliable data.

All Central Asian states experienced significant year-on-year increases in pollution. Tajikistan had the largest increase, registering 57.3 PM2.5/µg/m³ last year, compared to 46.3/µg/m³ in 2024. Uzbekistan had the smallest increase, with 31.4  PM2.5/µg/m³ recorded in 2024 and 38.1 PM2.5/µg/m³ last year.

PM2.5 is defined as fine particulate aerosol particles measuring up to 2.5 microns in diameter. PM2.5 are produced by vehicle exhaust, heavy industrial processes, power generation, agriculture, construction, and coal and wood burning. Natural sources of PM2.5 include dust storms, forest fires and volcanic eruptions. 

In the Caucasus, Azerbaijan was the only state to show slight improvement in air quality. Accordingly, it moved down in the 2025 IQAir ranking to 59th, after placing 49th the prior year. Armenia (24th) had the worst air quality in the Caucasus in 2025, registering 26.9 PM2.5/µg/m³. Georgia placed 56th in the 2025 list.

The survey found that air quality declined around the globe. “Wildfires, bolstered by climate change, played a primary role in degrading global air quality in 2025,” the report stated. “Record emissions from Europe and Canada contributed to a global release of approximately 1,380 megatons of carbon from biomass burning.”

According to IQAir, only 14 percent of cities surveyed met or exceeded WHO standards for acceptable air quality. The 2024 survey showed 17 percent of cities met or exceeded those standards. In compiling the 2025 report, IQAir drew on data collected in 9,446 cities in 143 countries, regions, and territories.

The 25 most polluted cities in 2025 were concentrated in three countries: Pakistan, India and China. However, Karaganda, Kazakhstan, was 26th on the list, and Ferghana, Uzbekistan, was 30th.

By Eurasianet