Turbine complaints “absurd”

Sustainable Cannabis Cultivation leverages greenhouse design, renewable energy, automation, and water recapture to cut electricity use, emissions, and pesticides, delivering premium yields with natural light, smart sensors, and efficient HVAC and irrigation control.

Key Points

A data-driven, low-impact method that cuts energy, water, and chemicals while preserving premium yields.

✅ 70-90% less electricity vs. conventional indoor grows

✅ Natural light, solar, and rainwater recapture reduce footprint

✅ Automation, sensors, and HVAC stabilize microclimates

In the seven months since the Trudeau government legalized recreational marijuana use, licensed producers across the country have been locked in a frenetic race to grow mass quantities of cannabis for the new market.

But amid the rush for scale, questions of sustainability have often taken a back seat, and in Canada, solar adoption has lagged in key sectors.

According to EQ Research LLC, a U.S.-based clean-energy consulting firm, cannabis facilities can need up to 150 kilowatt-hours of electricity per year per square foot. Such input is on par with data centres, which are themselves 50 to 200 times more energy-intensive than a typical office building, and achieving zero-emission electricity by 2035 would help mitigate the associated footprint.

At the Lawrence Berkley National Laboratory in California, a senior scientist estimated that one per cent of U.S. electricity use came from grow ops. The same research — published in 2012 — also found that the procedures for refining a kilogram of weed emit around 4,600 kilograms of carbon dioxide to the atmosphere, equivalent to operating three million cars for a year, though a shift to zero-emissions electricity by 2035 could substantially cut those emissions.

“All factors considered, a very large expenditure of energy and consequent ‘environmental imprint’ is associated with the indoor cultivation of marijuana,” wrote Ernie Small, a principal research scientist for Agriculture and Agri-Food Canada, in the 2018 edition of the Biodiversity Journal.

Those issues have left some turning to technology to try to reduce the industry’s footprint — and the economic costs that come with it — even as more energy sources make better projects for forward-looking developers.

“The core drawback of most greenhouse environments is that you’re just getting large rooms, which are harder to control,” says Dan Sutton, the chief executive officer of Tantalus Labs., a B.C.-based cannabis producer. “What we did was build a system specifically for cannabis.”

Sutton is referring to SunLab, the culmination of four years of construction, and at present the main site where his company nurtures rows of the flowering plant. The 120,000-square foot structure was engineered for one purpose: to prove the merits of a sustainable approach.

“We’re actually taking time-series data on 30 different environmental parameters — really simple ones like temperature and humidity — all the way down to pH of the soil and water flow,” says Sutton. “So if the temperature gets a little too cold, the system recognizes that and kicks on heaters, and if the system senses that the environment is too hot in the summertime, then it automatically vents.”

A lot is achieved without requiring much human intervention, he adds. Unlike conventional indoor operations, SunLab demands up to 90 per cent less electricity, avoids using pesticides, and draws from natural light and recaptured rainwater to feed its crops.

The liquid passes through a triple-filtration process before it is pumped into drip irrigation tubing. “That allows us to deliver a purity of water input that is cleaner than bottled water,” says Sutton.

As transpiration occurs, a state-of-the-art, high-capacity airflow suspended below the ceiling cycles air at seven-minute intervals, repeatedly cooling the air and preventing outbreaks of mould, while genetically modified “guardian” insects swoop in to eliminate predatory pests.

“When we first started, people never believed we would cultivate premium quality cannabis or cannabis that belongs on the top shelf, shoulder to shoulder with the best in the world and the best of indoor,” says Sutton.

Challenges still exist, but they pale in comparison to the obstacles that American companies with an interest in adopting greener solutions persistently face, and in provinces like Alberta, an Alberta renewable energy surge is reshaping the opportunity set.

Although cannabis is legal in a number of states, it remains illegal federally, which means access to capital and regulatory clarity south of the border can be difficult to come by.

“Right now getting a new project built is expensive to do because you can’t get traditional bank loans,” says Canndescent CEO Adrian Sedlin, speaking by phone from California.

In retrofitting the company’s farm to accommodate a sizeable solar field, he struggled to secure investors, even as a solar-powered cannabis facility in Edmonton showcased similar potential.

“We spent over a year and a half trying to get it financed,” says Sedlin. “Finding someone was the hard part.”

Decriminalizing the drug would ultimately increase the supply of capital and lower the costs for innovative designs, something Sedlin says would help incentivize producers to switch to more effective and ecologically sound techniques.

Some analysts argue that selling renewable energy in Alberta could become a major growth avenue that benefits energy-intensive industries like cannabis cultivation.

Canndescent, however, is already there.

“We’re now harnessing the sun to reduce our reliance on fossil fuels and going to sustainable, or replenishable, energy sources, while leveraging the best and most efficient water practices,” says Sedlin. “It’s the right thing to do.”

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Western Lithium Supply Localization is accelerating as EV battery makers diversify from China, boosting lithium hydroxide sourcing in North America and Europe, amid Covid-19 disruptions and rising prices, with geothermal brines and local processing.

Key Points

An industry shift to source lithium and processing near EV hubs, reducing China reliance and supply chain risk.

✅ EV makers seek North American and European lithium hydroxide

✅ Prices rise amid Covid-19 and logistics constraints

✅ New extraction: geothermal and oilfield brine projects

The global outbreak of coronavirus will accelerate efforts by western carmakers to localise supplies of lithium for electric car batteries, according to US producer Livent.

The industry was keen to diversify away from China, which produces the bulk of the world’s lithium, a critical material for lithium-ion batteries, said Paul Graves, Livent’s chief executive.

“It’s a conversation that’s starting to happen that was not happening even six months ago,” especially in the US, the former Goldman Sachs banker added.

China produced about 79 per cent of the lithium hydroxide used in electric car batteries last year, according to consultancy CRU, a supply chain that has been disrupted by the virus outbreak and EV shortages in some markets.

Prices for lithium hydroxide rose 3.1 per cent last month, their first increase since May 2018, according to Benchmark Mineral Intelligence, due to the impact of the Covid-19 bug.

Chinese lithium producer Ganfeng Lithium, which supplies major carmakers from Tesla to Volkswagen, said it had raised prices by less than 10 per cent, due to higher production costs and logistical difficulties.

“We can get lithium from lots of places . . . is that really something we’re prepared to rely upon?” Mr Graves said. “People are going to relook at supply chains, including battery recycling initiatives that enhance resilience, and relook at their integrity . . . and they’re going to say is there something we need to do to change our supply chains to make them more shockproof?”

General Motors last week said it was looking to source battery minerals such as lithium and nickel from North America for its new range of electric cars that will use cells made in Ohio by South Korea’s LG Chem.

“Some of these critical minerals could be challenging to obtain; it’s not just cobalt you need to be concerned about but also battery-grade nickel and lithium as well,” said Andy Oury, a lead engineer for batteries at GM. “We’re doing all of this with an eye to sourcing as much of the raw material from North America as possible.”

However, George Heppel, an analyst at CRU, warned it would be difficult to compete with China on costs. “China is always going to be the most competitive place to buy battery raw materials. That’s not likely to change anytime soon,” he said.

Livent, which extracts lithium from brines in northern Argentina, is looking at extracting the mineral from geothermal resources in the US and also wants to build a processing plant in Europe.

The Philadelphia-based company is also working with Canadian start-up E3 Metals to extract lithium from brines in Alberta's oil and gasfields for new projects in Canada.

“We’ll look at doing more in the US and more in Europe,” said Mr Graves, underscoring evolving Canada-U.S. collaboration across EV supply chains.

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New Brunswick Small Modular Reactors promise clean energy, jobs, and economic growth, say NB Power, ARC Nuclear, and Moltex Energy; critics cite cost overruns, nuclear waste risks, market viability, and reliance on government funding.

Key Points

Compact reactors proposed in NB to deliver low-carbon power and jobs; critics warn of costs, waste, and market risks.

✅ Promised jobs, exports, and net-zero support via NB Power partnerships

✅ Critics cite cost overruns, nuclear waste, and weak market demand

✅ Government funding pivotal; ARC and Moltex advance licensing

When Mike Holland talks about small modular nuclear reactors, he sees dollar signs.

When the Green Party hears about them, they see danger signs.

The loquacious Progressive Conservative minister of energy development recently quoted NB Power's eye-popping estimates of the potential economic impact of the reactors: thousands of jobs and a $1 billion boost to the provincial economy.

"New Brunswick is positioned to not only participate in this opportunity, but to be a world leader in the SMR field," Holland said in the legislature last month.

'Huge risk' nuclear deal could let Ontario push N.B. aside, says consultant
'Many issues' with modular nuclear reactors says environmental lawyer
Green MLAs David Coon and Kevin Arseneau responded cheekily by ticking off the Financial and Consumer Services Commission's checklist on how to spot a scam.

Is the sales pitch from a credible source? Is the windfall being promised by a reputable institution? Is the risk reasonable?

For small nuclear reactors, they said, the answer to all those questions is no. 

"The last thing we need to do is pour more public money down the nuclear-power drain," Coon said, reminding MLAs of the Point Lepreau refurbishment project that went $1 billion over budget.

The Greens aside, New Brunswick politicians have embraced small modular reactors as part of a broader premiers' nuclear initiative to develop SMR technology, which they say can both create jobs and help solve the climate crisis.

Smaller and cheaper, supporters say
They're "small" because, depending on the design, they would generate from three to 300 megawatts of electricity, less than, for example, Point Lepreau's 660 megawatts.

It's the modular design that is supposed to make them more affordable, as explained in next-gen nuclear guides, with components manufactured elsewhere, sometimes in existing factories, then shipped and assembled. 

Under Brian Gallant, the Liberals handed $10 million to two Saint John companies working on SMRs, ARC Nuclear and Moltex Energy.

Greens point to previous fiascoes
The Greens and other opponents of nuclear power fear SMRS are the latest in a long line of silver-bullet fiascoes, from the $23 million spent on the Bricklin in 1975 to $63.4 million in loans and loan guarantees to the Atcon Group a decade ago.

"It seems that [ARC and Moltex] have been targeting New Brunswick for another big handout ... because it's going to take billions of dollars to build these things, if they ever get off the drawing board," said Susan O'Donnell, a University of New Brunswick researcher.

O'Donnell, who studies technology adoption in communities, is part of a small new group called the Coalition for Responsible Energy Development formed this year to oppose SMRs.

"What we really need here is a reasonable discussion about the pros and cons of it," she said.

Government touts economic spinoffs
According to the Higgs government's throne speech last month, if New Brunswick companies can secure just one per cent of the Canadian market for small reactors, the province would see $190 million in revenue. 

The figures come from a study conducted for NB Power by University of Moncton economist Pierre-Marcel Desjardins.

But a four-page public summary does not include any sales projections and NB Power did not provide them to CBC News. 

"What we didn't see was a market analysis," O'Donnell said. "How viable is the market? … They're all based on a hypothetical market that probably doesn't exist."

O'Donnell said her group asked for the full report but was told it's confidential because it contains sensitive commercial information.

Holland said he's confident there will be buyers. 

"It won't be hard to find communities that will be looking for a cost effective, affordable, safe alternative to generate their electricity and do it in a way that emits zero emissions," he said.

SMRs come in different sizes and while some proponents talk about using "micro" reactors to provide electricity to remote northern First Nations communities, ARC and Moltex plan larger models to sell to power utilities looking to shift away from coal and gas.

"We have utilities and customers across Canada, where Ontario's first SMR groundbreaking has occurred already, across the United States, across Asia and Europe saying they desperately want a technology like this," said Moltex's Saint John-based CEO for North America Rory O'Sullivan. 

"The market is screaming for this product," he said, adding "all of the utilities" in Canada are interested in Moltex's reactors

ARC's CEO Norm Sawyer is more specific, guessing 30 per cent of his SMR sales will be in Atlantic Canada, 30 per cent in Ontario, where Darlington SMR plans are advancing, and 40 per cent in Alberta and Saskatchewan — all provincial power grids.

O'Donnell said it's an important question because without a large number of guaranteed sales, the high cost of manufacturing SMRs would make the initiative a money-loser. 

The cost of building the world's only functioning SMR, in Russia, was four times what was expected. 

An Australian government agency said initial cost estimates for such major projects "are often initially too low" and can "overrun." 

Up-front costs can be huge
University of British Columbia physicist M.V. Ramana, who has authored studies on the economics of nuclear power, said SMRs face the same financial reality as any large-scale manufacturing.

"You're going to spend a huge amount of money on the basic fixed costs" at the outset, he said, with costs per unit becoming more viable only after more units are built and sold. 

He estimates a company would have to build and sell more than 700 SMRs to break even, and said there are not enough buyers for that to happen. 

But Sawyer said those estimates don't take into account technological advances.

"A lot of what's being said ... is really based on old technology," he said, estimating ARC would be viable even if it sold an amount of reactors in the low double digits. 

O'Sullivan agrees.

"In fact, just the first one alone looks like it will still be economical," he said. "In reality, you probably need a few … but you're talking about one or two, maximum three [to make a profit] because you don't need these big factories."

'Paper designs' prove nothing, says expert
Ramana doesn't buy it. 

"These are all companies that have been started by somebody who's been in the nuclear industry for some years, has a bright idea, finds an angel investor who's given them a few million dollars," he said.

"They have a paper design, or a Power Point design. They have not built anything. They have not tested anything. To go from that point … to a design that can actually be constructed on the field is an enormous amount of work." 

Both CEOs acknowledge the skepticism about SMRs.

'The market is screaming for this product,' said Moltex’s Saint John-based CEO for North America, Rory O’Sullivan. (Brian Chisholm, CBC)
"I understand New Brunswick has had its share of good investments and its share of what we consider questionable investments," said Sawyer, who grew up in Rexton.

But he said ARC's SMR is based on a long-proven technology and is far past the on-paper design stage "so you reduce the risk." 

Moltex is now completing the first phase of the Canadian Nuclear Safety Commission's review of its design, a major hurdle. ARC completed that phase last year.

But, Ramana said there are problems with both designs. Moltex's molten salt model has had "huge technical challenges" elsewhere while ARC's sodium-cooled system has encountered "operational difficulties."

Ottawa says nuclear is needed for climate goals
The most compelling argument for looking at SMRs may be Ottawa's climate change goals, and international moves like the U.K.'s green industrial revolution plan point to broader momentum.  

The national climate plan requires NB Power to phase out burning coal at its Belledune generating station by 2030. It's scrambling to find a replacement source of electricity.

The Trudeau government's throne speech in October promised to "support investments in renewable energy and next-generation clean energy and technology solutions."

And federal Natural Resources Minister Seamus O'Regan told CBC earlier this year that he's "very excited" about SMRs and has called nuclear key to climate goals in Canada as well.

"We have not seen a model where we can get to net-zero emissions by 2050 without nuclear,"  he said.

O'Donnell said while nuclear power doesn't emit greenhouse gases, it's hardly a clean technology because of the spent nuclear fuel waste. 

Government support is key 
She also wonders why, if SMRs make so much sense, ARC and Moltex are relying so much on government money rather than private capital.

Holland said "the vast majority" of funding for the two companies "has to come from private sector investments, who will be very careful to make sure they get a return on that investment."

Sawyer said ARC has three dollars for every dollar it has received from the province, and General Electric has a minority ownership stake in its U.S.-based parent company.

O'Sullivan said Moltex has attracted $5 million from a European engineering firm and $6 million from "the first-ever nuclear crowdfunding campaign." 

But he said for new technologies, including nuclear power, "you need government to show policy support.

"Nuclear technology has always been developed by governments around the world. This is a very new change to have an industry come in and lead this, so private investors can't take the risk to do that on their own," he said. 

So far, Ottawa hasn't put up any funding for ARC or Moltex. During the provincial election campaign, Higgs implied federal money was imminent, but there's been no announcement in the almost three months since then.

Last month the federal government announced $20 million for Terrestrial Energy, an Ontario company working on SMRs, alongside OPG's commitment to SMRs in the province, underscoring momentum.

"We know we have the best technology pitch," O'Sullivan said. "There's others that are slightly more advanced than us, but we have the best overall proposition and we think that's going to win out at the end of the day."

But O'Donnell said her group plans to continue asking questions about SMRs. 

"I think what we really need is to have an honest conversation about what these are so that New Brunswickers can have all the facts on the table," she said.

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US Nuclear Generating Costs 2017 show USD33.50/MWh for nuclear energy, the lowest since 2008, as capital expenditures, fuel costs, and operating costs declined after license renewals and uprates, supporting a reliable, low-carbon grid.

Key Points

The 2017 US nuclear average was USD33.50/MWh, lowest since 2008, driven by reduced capital, fuel, and operating costs.

✅ Average cost USD33.50/MWh, lowest since 2008

✅ Capital, fuel, O&M costs fell sharply since 2012 peak

✅ License renewals, uprates, market reforms shape competitiveness

Average total generating costs for nuclear energy in 2017 in the USA were at their lowest since 2008, according to a study released by the Nuclear Energy Institute (NEI), amid a continuing nuclear decline debate in other regions.

The report, Nuclear Costs in Context, found that in 2017 the average total generating cost - which includes capital, fuel and operating costs - for nuclear energy was USD33.50 per megawatt-hour (MWh), even as interest in next-generation nuclear designs grows among stakeholders. This is 3.3% lower than in 2016 and more than 19% below 2012's peak. The reduction in costs since 2012 is due to a 40.8% reduction in capital expenditures, a 17.2% reduction in fuel costs and an 8.7% reduction in operating costs, the organisation said.

The year-on-year decline in capital costs over the past five years reflects the completion by most plants of efforts to prepare for operation beyond their initial 40-year licence. A few major items - a series of vessel head replacements; steam generator replacements and other upgrades as companies prepared for continued operation, and power uprates to increase output from existing plants - caused capital investment to increase to a peak in 2012. "As a result of these investments, 86 of the [USA's] 99 operating reactors in 2017 have received 20-year licence renewals and 92 of the operating reactors have been approved for uprates that have added over 7900 megawatts of electricity capacity. Capital spending on uprates and items necessary for operation beyond 40 years has moderated as most plants are completing these efforts," it says.

Since 2013, seven US nuclear reactors have shut down permanently, with the Three Mile Island debate highlighting wider policy questions, and another 12 have announced their permanent shutdown. The early closure for economic reasons of reliable nuclear plants with high capacity factors and relatively low generating costs will have long-term economic consequences, the report warns: replacement generating capacity, when needed, will produce more costly electricity, fewer jobs that will pay less, and, for net-zero emissions objectives, more pollution, it says.

NEI Vice President of Policy Development and Public Affairs John Kotek said the "hardworking men and women of the nuclear industry" had done an "amazing job" reducing costs through the institute's Delivering the Nuclear Promise campaign and other initiatives, in line with IAEA low-carbon lessons from the pandemic. "As we continue to face economic headwinds in markets which do not properly compensate nuclear plants, the industry has been doing its part to reduce costs to remain competitive," he said.

"Some things are in urgent need of change if we are to keep the nation's nuclear plants running and enjoy their contribution to a reliable, resilient and low-carbon grid. Namely, we need to put in place market reforms that fairly compensate nuclear similar to those already in place in New York, Illinois and other states," Kotek added.

Cost information in the study was collected by the Electric Utility Cost Group with prior years converted to 2017 dollars for accurate historical comparison.

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Electricity System Climate Resilience underpins grid reliability amid heatwaves and drought, integrating solar, wind, hydropower, nuclear, storage, and demand response with efficient transmission, flexibility, and planning to secure power for homes, industry, and services.

Key Points

Power systems capacity to endure extreme weather and integrate clean energy, maintaining reliability and flexibility.

✅ Grid hardening, transmission upgrades, and digital forecasting.

✅ Flexible low-carbon supply: hydropower, nuclear, storage.

✅ Demand response, efficient cooling, and regional integration.

Summer is just half done in the northern hemisphere and yet we are already seeing electricity systems around the world struggling to cope with the severe strain of heatwaves and low rainfall.

These challenges highlight the urgent need for strong and well-planned policies and investments to improve the security of our electricity systems, which supply power to homes, offices, factories, hospitals, schools and other fundamental parts of our economies and societies. This means making our electricity systems more resilient to the effects of global warming – and more efficient and flexible as they incorporate rising levels of solar and wind power, as solar is now the cheapest electricity in history according to the IEA, which will be critical for reaching net-zero emissions in time to prevent even worse impacts from climate change.

A range of different countries, including the US, Canada and Iraq, have been hard hit by extreme weather recently in the form of unusually high temperatures. In North America, the heat soared to record levels in the Pacific Northwest. An electricity watchdog says that five US regions face elevated risks to the security of their electricity supplies this summer, underscoring US grid climate risks that could worsen, and that California’s risk level is even higher.

Heatwaves put pressure on electricity systems in multiple ways. They increase demand as people turn up air conditioning, driving higher US electricity bills for many households, and as some appliances work harder to maintain cool temperatures. At the same time, higher temperatures can also squeeze electricity supplies by reducing the efficiency and capacity of traditional thermal power plants, such as coal, natural gas and nuclear. Extreme heat can reduce the availability of water for cooling plants or transporting fuel, forcing operators to reduce their output. In some cases, it can result in power plants having to shut down, increasing the risk of outages. If the heat wave is spread over a wide geographic area, it also reduces the scope for one region to draw on spare capacity from its neighbours, since they have to devote their available resources to meeting local demand.

A recent heatwave in Texas forced the grid operator to call for customers to raise their thermostats’ temperatures to conserve energy. Power generating companies suffered outages at much higher rates than expected, providing an unwelcome reminder of February’s brutal cold snap when outages – primarily from natural gas power plants – left up to 5 million customers across the US without power over a period of four days.

At the same time, lower than average rainfall and prolonged dry weather conditions are raising concerns about hydropower’s electricity output in various parts of the world, including Brazil, China, India and North America. The risks that climate change brings in the form of droughts adds to the challenges faced by hydropower, the world’s largest source of clean electricity, highlighting the importance of developing hydropower resources sustainably and ensuring projects are climate resilient.

The recent spate of heatwaves and unusually long dry spells are fresh warnings of what lies ahead as our climate continues to heat up: an increase in the scale and frequency of extreme weather events, which will cause greater impacts and strains on our energy infrastructure.

Heatwaves will increase the challenge of meeting electricity demand while also decarbonizing the electricity supply. Today, the amount of energy used for cooling spaces – such as homes, shops, offices and factories – is responsible for around 1 billion tonnes of global CO2 emissions. In particular, energy for cooling can have a major impact on peak periods of electricity demand, intensifying the stress on the system. Since the energy demand used for air conditioners worldwide could triple by 2050, these strains are set to grow unless governments introduce stronger policy measures to improve the energy efficiency of air conditioning units.

Electricity security is crucial for smooth energy transitions
Many countries around the world have announced ambitious targets for reaching net-zero emissions by the middle of this century and are seeking to step up their clean energy transitions. The IEA’s recent Global Roadmap to Net Zero by 2050 makes it clear that achieving this formidable goal will require much more electricity, much cleaner electricity and for that electricity to be used in far more parts of our economies than it is today. This means electricity reaching much deeper into sectors such as transport (e.g. EVs), buildings (e.g. heat-pumps) and industry (e.g. electric-arc steel furnaces), and in countries like New Zealand's electrification plans it is accelerating broader efforts. As clean electricity’s role in the economy expands and that of fossil fuels declines, secure supplies of electricity become ever-more important. This is why the climate resilience of the electricity sector must be a top priority in governments’ policy agendas.

Changing climate patterns and more frequent extreme weather events can hit all types of power generation sources. Hydropower resources typically suffer in hot and dry conditions, but so do nuclear and fossil fuel power plants. These sources currently help ensure electricity systems have the flexibility and capacity to integrate rising shares of solar and wind power, whose output can vary depending on the weather and the time of day or year.

As governments and utilities pursue the decarbonization of electricity systems, mainly through growing levels of solar and wind, and carbon-free electricity options, they need to ensure they have sufficiently robust and diverse sources of flexibility to ensure secure supplies, including in the event of extreme weather events. This means that the possible decommissioning of existing power generation assets requires careful assessments that take into account the importance of climate resilience.

Ensuring electricity security requires long-term planning and stronger policy action and investment
The IEA is committed to helping governments make well-informed decisions as they seek to build a clean and secure energy future. With this in mind, here are seven areas for action for ensuring electricity systems are as resilient as possible to climate risks:

1. Invest in electricity grids to make them more resilient to extreme weather. Spending today is far below the levels needed to double the investment for cleaner, more electrified energy systems, particularly in emerging and developing economies. Economic recovery plans from the COVID-19 crisis offer clear opportunities for economies that have the resources to invest in enhancing grid infrastructure, but much greater international efforts are required to mobilize and channel the necessary spending in emerging and developing economies.

2. Improve the efficiency of cooling equipment. Cost-effective technology already exists in most markets to double or triple the efficiency of cooling equipment. Investing in higher efficiency could halve future energy demand and reduce investment and operating costs by $3 trillion between now and 2050. In advance of COP26, the Super-Efficient Equipment and Appliance Deployment (SEAD) initiative is encouraging countries to sign up to double the energy efficiency of equipment sold in their countries by 2030.

3. Enable the growth of flexible low-carbon power sources to support more solar and wind. These electricity generation sources include hydropower and nuclear, for countries who see a role for one or both of them in their energy transitions. Guaranteeing hydropower resilience in a warming climate will require sophisticated methods and tools – such as the ones implemented in Brazil – to calculate the necessary level of reserves and optimize management of reservoirs and hydropower output even in exceptional conditions. Batteries and other forms of storage, combined with solar or wind, can also provide important amounts of flexibility by storing power and releasing it when needed.

4. Increase other sources of electricity system flexibility. Demand-response and digital technologies can play an important role. The IEA estimates that only a small fraction of the huge potential for demand response in the buildings sector is actually tapped at the moment. New policies, which associate digitalization and financial behavioural incentives, could unlock more flexibility. Regional integration of electricity systems across national borders can also increase access to flexible resources.

5. Expedite the development and deployment of new technologies for managing extreme weather threats. The capabilities of electricity utilities in forecasting and situation awareness should be enhanced with the support of the latest information and communication technologies.

6. Make climate resilience a central part of policy-making and system planning. The interconnected nature of recent extreme weather events reminds us that we need to account for many contingencies when planning resilient power systems. Climate resilience should be integral to policy-making by governments and power system planning by utilities and relevant industries, and debates over Canadian climate policy underscore how grid implications must be considered. According to the recent IEA report on climate resilience, only nine out of 38 IEA member and association countries include concrete actions on climate adaptation and resilience for every segment of electricity systems.

7. Strengthen international cooperation on electricity security. Electricity underpins vital services and basic needs, such as health systems, water supplies and other energy industries. Maintaining a secure electricity supply is thus of critical importance. The costs of doing nothing in the face of growing climate threats are becoming abundantly clear. The IEA is working with all countries in the IEA family, as well as others around the world, by providing unrivalled data, analysis and policy advice on electricity security issues. It is also bringing governments together at various levels to share experiences and best practices, and identify how to hasten the shift to cleaner and more resilient energy systems.

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ADNOC Hydrogen Export Projects target global energy transition, courting investors and equity stakes for blue and green hydrogen, ammonia shipping, CCS at Ruwais, and long-term supply contracts across power, transport, and industrial sectors.

Key Points

ADNOC plans blue and green hydrogen exports, leveraging Ruwais, CCS, and ammonia to secure long-term supply.

✅ Blue hydrogen via gas reforming with CCS; ammonia for shipping.

✅ Green hydrogen from solar-powered electrolysis under development.

✅ Ruwais expansions and Fertiglobe ammonia tie-up target long-term supply.

Abu Dhabi is seeking investors to help build hydrogen-export facilities, as Middle Eastern oil producers plan to adopt cleaner energy solutions, sources told Bloomberg.

Abu Dhabi National Oil Company (ADNOC) is holding talks with energy companies for them to purchase equity stakes in the hydrogen projects, the sources referred, as Germany's hydrogen strategy signals rising import demand.

ADNOC, which already produces hydrogen for its refineries, also aims to enter into long-term supply contracts, as Canada-Germany clean energy cooperation illustrates growing cross-border demand, before making any progress with these investments.

Amid a global push to reduce greenhouse-gas emissions, the state-owned oil companies in the Gulf region seek to turn their expertise in exporting liquid fuel into shipping hydrogen or ammonia across the world for clean and universal electricity needs, transport, and industrial use.

Most of the ADNOC exports are expected to be blue hydrogen, created by converting natural gas and capturing the carbon dioxide by-product that can enable using CO2 to generate electricity approaches, according to Bloomberg.

The sources said that the Abu Dhabi-based company will raise its production of hydrogen by expanding an oil-processing plant and the Borouge petrochemical facility at the Ruwais industrial hub, supporting a sustainable electric planet vision, as the extra hydrogen will be used for an ammonia facility planned with Fertiglobe.

Abu Dhabi also plans to develop green hydrogen, similar to clean hydrogen in Canada initiatives, which is generated from renewable energy such as solar power.

Noteworthy to mention, in May 2021, ADNOC announced that it will construct a world-scale blue ammonia production facility in Ruwais in Abu Dhabi to contribute to the UAE's efforts to create local and international hydrogen value chains.

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