EV future may power a charging industry

By Reuters


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As makers from Tesla to Nissan Motor Company jockey to dominate the next generation electric-powered cars, a fight on which companies will control the lucrative market to fuel them is just getting started.

U.S. President Barack Obama aims to put a million electric vehicles on the road by 2015 as part of the new U.S. effort to cut greenhouse gas emissions linked to global warming.

Cars are sexier than gas pumps or charging stations, but as the history of the oil industry shows, fuel is big business. A million electric cars will need a lot of power and a complex system to make sure the grid is not overwhelmed.

"Your head starts spinning when you think of what the possibilities and opportunities are but also the complexity," said Bill Nicholson, who leads the electric vehicle initiative at Portland General Electric in Oregon.

He does not expect utilities to be big players in setting up charging stations although they will provide the power.

"There will be some pretty large players in the charging station infrastructure business who will then partner with some pretty large players in the information side of this, the IBMs of the world and others that do nationwide deployment of standardized charging stations," he predicted.

Politics are sure to shape the economics of the industry. The Climate Change bill that has passed the U.S. House of Representatives and is being considered by the Senate requires utilities to draw up plans for charging electric vehicles. It also sets financial incentives to set up charging stations and subsidies for people buying electric cars.

Many wonder if electric vehicle sales will take off. Automakers sold only about 160,000 hybrids, or 2.8 percent of total sales, in the U.S. this year through July, according to Autodata.

Plug-in hybrids, which are part of Obama's goal of having one million electric cars on the roads by 2015, may account for 25 percent of auto sales by 2020, according to separate studies by the Department of Energy and environmental groups.

Electric cars can be smooth, quiet and environmentally friendly. But they must deliver clear operating savings, since their price tag may initially be higher than conventional vehicles. Nissan roughly sees their operating cost equivalent to $1.10 per gallon of gasoline.

Skeptics say charging stations won't be a viable business because drivers will top off batteries at home, except on long trips, and won't want to pay a premium for electricity.

"We've found that about 90 percent of our customers' charging happens at home," said JB Straubel, Chief Technology Officer of Tesla Motors, maker of a $100,000-plus electric sports car whose 300-mile range is triple that of mass market vehicles from other makers due to enter the market late next year.

Proponents counter that charge stations will proliferate once there are a million or more electric cars on the roads. Most charging will be done at home, but some cars don't even have a garage.

"If you live in San Francisco, 51 percent of all cars are parked curbside at night," said Richard Lowenthal, founder and CEO of Coulomb Technologies, which aims to sell about a thousand charging stations this year at $2,000-plus each.

"I ship a station, I keep $1,000," said Lowenthal. He expects five times as many sales next year. But he says electric charge stations will offer a lot more than a plug.

Company founders included former executives of Internet equipment maker Cisco Systems Inc, and Coulomb sees services such as finding a free charge spot by cell phone as key to its potential success.

A University of California, Berkeley study says as much as $320 billion will be spent on charging infrastructure over the next couple of decades. The U.S. Department of Energy recently awarded $2.4 billion in electric-vehicle related grants.

Technology being developed by the industry will cut the time it takes to charge a car battery from hours to between 10 and 45 minutes. That won't be possible in most homes, but it should make long trips much easier.

"That's kind of a game changer because then you can do fast charging and it's competitive with gasoline," said Jeff Kim, president of privately held Shorepower Technologies, which already has charging stations at truck stops to run air conditioners on big rigs while drivers sleep.

A big roll-out of charging stations could come in about six months said, Kristen Helsel, director of electric vehicles at AeroVironment Inc.

"What's really important is we go in before the cars, but not a whole lot before the cars," she said.

Views about who could own the stations are all over the map. Equipment makers could deploy stations themselves, parking garage and restaurant owners could buy them for their properties, and larger networks might be set up by independent operators or companies who see charging as part of a bigger business of providing services to electric car owners.

Lowenthal has sold chargers to a McDonald's restaurant and his own landlord. Both hope to attract 'green' clients, he said. He's also had interest from financiers.

Entrepreneur Ron Percival, of PowerUp Systems Inc., is buying Shorepower stations and plans a network of 'e-Stations' in Vancouver, Seattle and Toronto in time for the Vancouver 2010 winter Olympics. If successful he will expand in the Pacific Northwest and Canada.

A big question is whether municipalities and utilities will take on charging. Better Place, a California company with $300 million in funding and plans to build networks from Australia to the San Francisco Bay Area, says cities and power companies won't do more than set up 'seed' stations.

"For real adoption you need to have real numbers. You can't have people driving around looking for a charge spot because it won't work," said Sidney Goodman, vice-president of Automotive Alliances at Better Place.

Better Place plans to lease batteries to drivers along with charging facilities. Motorists will be able to swap spent batteries at its stations and the company will develop a computer network to make the process easier.

The company has not yet raised the money it will need to begin operations in the United States, but it has started investing an expected $150 million to $200 million into deploying 100,000 charging spots and stations to swap out depleted batteries in its first deployment, Israel.

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ACCIONA Energía Launches 280 MW Wind Farm in Alberta

Forty Mile Wind Farm delivers 280 MW of renewable wind power in Alberta, with 49 Nordex turbines by ACCIONA Energía, supplying clean electricity to the grid, lowering carbon emissions, and enabling future 120 MW expansion.

 

Key Points

A 280 MW ACCIONA Energía wind farm in Alberta with 49 Nordex turbines, delivering clean power and cutting carbon.

✅ 280 MW via 49 Nordex N155 turbines on 108 m towers

✅ Supplies clean power to 85,000+ homes, reducing emissions

✅ Phase II could add 120 MW, reaching 400 MW capacity

 

ACCIONA Energía, a global leader in renewable energy, has successfully launched its Forty Mile Wind Farm in southern Alberta, Canada, amid momentum from a new $200 million wind project announced elsewhere in the province. This 280-megawatt (MW) project, powered by 49 Nordex turbines, is now supplying clean electricity to the provincial grid and stands as one of Canada's ten largest wind farms. It also marks the company's largest wind installation in North America to date. 

Strategic Location and Technological Specifications

Situated approximately 50 kilometers southwest of Medicine Hat, the Forty Mile Wind Farm is strategically located in the County of Forty Mile No. 8. Each of the 49 Nordex N155 turbines boasts a 5.7 MW capacity and stands 108 meters tall. The project's design allows for future expansion, with a potential Phase II that could add an additional 120 MW, bringing the total capacity to 400 MW, a scale comparable to Enel's 450 MW U.S. wind farm now in operation. 

Economic and Community Impact

The Forty Mile Wind Farm has significantly contributed to the local economy. During its peak construction phase, the project created approximately 250 jobs, with 25 permanent positions anticipated upon full operation. These outcomes align with an Alberta renewable energy surge projected to power thousands of jobs across the province. Additionally, the project has injected new tax revenues into the local economy and provided direct financial support to local non-profit organizations, including the Forty Mile Family & Community Support Services, the Medicine Hat Women’s Shelter Society, and the Root Cellar Food & Wellness Hub. 

Environmental Benefits

Once fully operational, the Forty Mile Wind Farm is expected to generate enough clean energy to power more than 85,000 homes, supporting wind power's competitiveness in electricity markets today. This substantial contribution to Alberta's energy mix aligns with ACCIONA Energía's commitment to sustainability and its goal of reducing carbon emissions. The project is part of the company's broader strategy to expand its renewable energy footprint in North America and support the transition to a low-carbon economy. 

Future Prospects

Looking ahead, ACCIONA Energía plans to continue its expansion in the renewable energy sector, as peers like TransAlta add 119 MW in the U.S. to their portfolios. The success of the Forty Mile Wind Farm serves as a model for future projects and underscores the company's dedication to delivering sustainable energy solutions, even as Alberta's energy future presents periodic headwinds. With ongoing developments and a focus on innovation, ACCIONA Energía is poised to play a pivotal role in shaping the future of renewable energy in North America.

The Forty Mile Wind Farm exemplifies ACCIONA Energía's commitment to advancing renewable energy, supporting local communities, and contributing to environmental sustainability, and it benefits from evolving demand signals, including a federal green electricity contract initiative in Canada that encourages clean supply. As the project continues to operate and expand, it stands as a testament to the potential of wind energy in Canada's clean energy landscape.

 

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Ontario Launches Peak Perks Program

Ontario Peak Perks Program boosts energy efficiency with smart thermostats, demand response, and incentives, reducing peak demand, electricity costs, and emissions while supporting grid reliability and Save on Energy initiatives across Ontario businesses and homes.

 

Key Points

A demand response initiative offering incentives via smart thermostats to cut peak electricity use and lower costs

✅ $75 sign-up, $20 yearly enrollment incentive

✅ Up to 10 summer temperature events; opt-out anytime

✅ Expanded retrofits, greenhouse support, grid savings

 

The Ontario government is launching the new Peak Perks program to help families save money by conserving energy, building on bill support during COVID-19 initiatives as part of the government’s $342 million expansion of Ontario’s energy-efficiency programs that will reduce demands on the provincial grid. The government is also launching three new and enhanced programs for businesses, municipalities, and other institutions, including targeted support for greenhouse growers in Southwest Ontario.

“Our government is giving families more ways to lower their energy bills with new energy-efficiency programs like Peak Perks and ultra-low overnight rates available to consumers, which will provide families a $75 financial incentive this year in exchange for lowering their energy use at peak times during the summer,” said Todd Smith, Minister of Energy. “The new programs launched today will also help meet the province’s emerging electricity system needs by providing annual electricity savings equivalent to powering approximately 130,000 homes every year and, alongside electricity cost allocation discussions, reduce costs for consumers by over $650 million by 2025.”

The new Peak Perks program provides a financial incentive for residential customers who are willing to conserve energy and reduce their air conditioning at peak times and have an eligible smart thermostat connected to a central air conditioning system or heat pump unit. Participants will receive $75 for enrolling this year, as well as $20 for each year they stay enrolled in the program starting in 2024.

Residential customers can participate in Peak Perks by enrolling and giving their thermostat manufacturer secure access to their thermostat. Participants will be notified when one of the maximum 10 annual temperature change events occurs directly by their thermostat manufacturer on their mobile app and on their thermostat. Peak Perks has been designed to ensure participants are always in control and customers can opt-out of any temperature change event without impacting their incentive.

The Peak Perks program will be available starting in June. Interested customers can visit SaveOnEnergy.ca/PeakPerks today to sign-up for the program waitlist and receive an email notice with information on how to enroll.

In addition to the financial incentive provided by Peak Perks, reducing electricity use during peak demand hours in the summer months helps customers to lower their monthly electricity bills, and measures such as a temporary off-peak rate freeze have complemented these efforts, as these periods tend to be associated with the highest costs for power. Lowering demand during peak periods also allows the province to reduce electricity sector emissions, by reducing the need for electricity generation facilities that only run at times of peak demand such as natural gas.

Ontario has also launched three new and enhanced programs, including an expanded custom Retrofit program for business, municipalities and other institutions, and industrial electricity rate relief initiatives, targeted support for greenhouse growers in Southwest Ontario, as well enhancements to the existing Local Initiatives Program. The expanded Retrofit program alone will feature over $200 million in dedicated funding to support the new custom energy-efficiency retrofit project stream, that will cover up to 50 percent of the cost of approved projects.

These new and expanded energy-efficiency programs are expected to have a strong impact in Southwest Ontario, with regional peak demand savings of 225 megawatts (MW). This, together with the Ontario-Quebec energy swap agreement, will provide additional capacity for the region and support growing economic development. The overall savings from this energy-efficiency programming will result in an estimated three million tonnes of greenhouse gas emission reductions over its lifetime - the equivalent to taking more than 600,000 vehicles off the road for one year.

“Thanks to energy efficiency efforts over the past 15 years, demand for electricity is today about 12 per cent lower than it otherwise would be,” said Lesley Gallinger, President and CEO, of the Independent Electricity System Operator, Ontario’s grid operator and provider of Save on Energy programs to home and business consumers. “Conservation is a valuable and cost-effective resource that supports system reliability and helps drive economic development as we strive towards compliance with clean electricity regulations for a decarbonized electricity grid.”

 

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Financial update from N.L energy corp. reflects pandemic's impact

Nalcor Energy Pandemic Loss underscores Muskrat Falls delays, hydroelectric risks, oil price shocks, and COVID-19 impacts, affecting ratepayers, provincial debt, timelines, and software commissioning for the Churchill River project and Atlantic Canada subsea transmission.

 

Key Points

A $171M Q1 2020 downturn linked to COVID-19, oil price collapse, and Muskrat Falls delays impacting schedules and costs.

✅ Q1 2020 profit swing: +$92M to -$171M amid oil price crash

✅ Muskrat Falls timeline slips; cost may reach $13.1B

✅ Software, workforce, COVID-19 constraints slow commissioning

 

Newfoundland and Labrador's Crown energy corporation reported a pandemic-related profit loss from the first quarter of 2020 on Tuesday, along with further complications to the beleaguered Muskrat Falls hydroelectric project.

Nalcor Energy recorded a profit loss of $171 million in the first quarter of 2020, down from a $92 million profit in the same period last year, due in part to falling oil prices during the COVID-19 pandemic.

The company released its financial statements for 2019 and the first quarter of 2020 on Tuesday, and officials discussed the numbers in a livestreamed presentation that detailed the impact of the global health crisis on the company's operations.

The loss in the first quarter was caused by lower profits from electricity sales and a drop in oil prices due to the pandemic and other global events, company officials said.

The novel coronavirus also added to the troubles plaguing the Muskrat Falls hydroelectric dam on Labrador's Churchill River, amid Quebec-N.L. energy tensions that long predate the pandemic.

Work at the remote site stopped in March over concerns about spreading the virus. Operations have been resuming slowly, with a reduced workforce tackling the remaining jobs.

Officials with Nalcor said it will likely be another year before the megaproject is complete.

CEO Stan Marshall estimates the months of delays could bring the total cost to $13.1 billion including financing, up from the previous estimate of $12.7 billion -- though the total impact of the coronavirus on the project's price tag has yet to be determined.

"If we're going to shut down again, all of that's wrong," Marshall said. "But otherwise, we can just carry on and we'll have a good idea of the productivity level. I'm hoping that by September we'll have a more definitive number here."

The 824 megawatt hydroelectric dam will eventually send power to Newfoundland, and later Nova Scotia, through subsea cables, even as Nova Scotia boosts wind and solar in its energy mix.

It has seen costs essentially double since it was approved in 2012, and faced significant delays even before pandemic-forced shutdowns in North America and around the world this spring.

Cost and schedule overruns were the subject of a sweeping inquiry that held hearings last year, while broader generation choices like biomass use have drawn scrutiny as well.

The commissioner's report faulted previous governments for failing to protect residents by proceeding with the project no matter what, and for placing trust in Nalcor executives who "frequently" concealed information about schedule, cost and related risks.

Some of the latest delays have come from challenges with the development of software required to run the transmission link between Labrador and Newfoundland, where winter reliability issues have been flagged in reports.

The software is still being worked out, Marshall said Tuesday, and the four units at the dam will come online gradually over the next year.

"It's not an all or nothing thing," Marshall said of the final work stages.
Nalcor's financial snapshot follows a bleak fiscal update from the province this month. The Liberal government reported a net debt of $14.2 billion and a deficit of more than $1.1 billion, even as a recent Churchill Falls deal promised new revenues for the province, citing challenges from pandemic-related closures and oil production shutdowns.

Finance Minister Tom Osborne said at the time that help from Ottawa will be necessary to get the province's finances back on track.

Muskrat Falls represents about one-third of the province's debt, and is set to produce more power than the province of about half a million people requires. Anticipated rate increases due to the ballooning costs and questions about Muskrat Falls benefits have posed a significant political challenge for the provincial government.

Ottawa has agreed to work with Newfoundland and Labrador on a rewrite of the project's financial structure, scrapping the format agreed upon in past federal-provincial loan agreements in order to ease the burden on ratepayers, while some argue independent planning would better safeguard ratepayers.

Marshall, a former Fortis CEO who was brought in to lead Nalcor in 2016, has called the project a "boondoggle" and committed to seeing it completed within four years. Though that plan has been disrupted by the pandemic, Marshall said the end is in sight.

"I'm looking forward to a year from now. And I hope to be gone," Marshall said.

 

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The Banker Trying to Fix the UK's Electricity Grid

UK power grid bottleneck is stalling renewable energy, with connection queues, planning delays, and transmission infrastructure gaps raising costs, slowing decarbonization, and deterring investment as government considers reforms led by a new chief adviser.

 

Key Points

Delays and capacity gaps that hinder connecting new generation and demand, raising costs and slowing decarbonization.

✅ Connection queues delay projects for years

✅ Planning and NIMBY barriers stall transmission builds

✅ Investment costs on bills risk political pushback

 

During his three decades at investment bank Morgan Stanley, Franck Petitgas developed a reputation for solving problems that vexed others. Fixing the UK’s creaking power grid could be his most challenging task yet.

Earlier this year, Prime Minister Rishi Sunak appointed Petitgas as his chief business adviser, and the former financier has been pushing to tackle the gridlock that’s left projects waiting endlessly for a connection, an issue he sees as one of the biggest problems for industry.

But there are no easy solutions to tackle the years-long queue to get on the grid or the drawn-out planning process for building clean power generation, with the energy transition stalled by supply delays compounding the problem. And sluggish progress in expanding and improving the electricity network is preventing the construction of new housing developments and offices, as well as slowing the transition to greener power.

That transition has already taken a knock after Sunak last week controversially watered down some of the UK’s climate ambitions, citing in part the cost to consumers. He also acknowledged the issues surrounding the grid and promised the “most transformative plans” in response, drawing on lessons from Europe’s power crisis where applicable. Those are due to be unveiled within weeks. 

Shortly after his appointment, Petitgas offered reassurances to business leaders at a meeting in Downing Street that solutions were being worked on, according to people familiar with the matter. But there’s a lack of confidence across business that enough will be done.

Cost is a big factor in the expansion of the electricity grid, and some argue a state-owned generation model could ease bills over time. Improving the onshore network alone could require investment of between £100 billion and £240 billion ($122-$293 billion) by 2050, according to a government analysis last year. 

With network expansion funded through power bills, that’s a big ask, particularly with Sunak trailing in polls ahead of an election expected next year.

“It’s very difficult for politicians to say more money should be on bills,” said Emma Pinchbeck, chief executive of Energy UK, a trade body. “So you get to a situation where no one wants to pay for the infrastructure investment until it’s really sticky, and that’s where we’ve got to with the grid.”

There are huge competitive and economic implications if the UK falls further behind. With US President Joe Biden spending an estimated $370 billion on climate measures through his Inflation Reduction Act, and China already a world leader in electric vehicles, Britain’s grid inaction is holding it back in the global race to decarbonize, said Jess Ralston, an analyst at the Energy and Climate Intelligence Unit think tank.

“The UK is dithering and delaying, and not making any strategic decisions,” she said. “You can see companies just saying ‘I’m going to the US, or I’m going to China’.” 

In a statement, the government said it’s a “priority to speed up the time taken to connect new power generators and power consumers to the grid.” It added that it’s taking “significant steps to accelerate grid infrastructure,” including support for new Channel interconnectors announced this year.

The government expects demand for electricity to double by 2035 and that will mean more generation that needs to be linked up to the network by cables and pylons. Local grids will also have to expand to accommodate more connection points for electric vehicles and homes, and invest in large-scale energy storage capacity to balance supply.

But so far, the rapid rise in renewable energy investment has not been accompanied by matching spend on the power network, according to BloombergNEF, a pattern seen in Germany’s grid expansion woes as well.

“The pace and scale of what we now have to deliver is significantly different from the last few decades,” said Carl Trowell, president of UK strategic infrastructure at National Grid. “It’s a national endeavor.”

In June, Electricity Networks Commissioner Nick Winser sent the government recommendations for how to accelerate construction of more transmission infrastructure. He said efforts to decarbonize the power sector will be “wasted if we cannot get the power to homes and businesses.”

“We need a seriously stronger sense of urgency,” said Kevin O’Donovan, country manager for Statkraft UK, which is holding off investment in four wind farms and two solar projects due to grid connection delays.

In addition to cost, the other major stumbling block is planning. Politicians in the governing Conservative Party are wary of angering voters with new infrastructure in rural areas that typically vote Tory. Across the country, “Not In My Back Yard” campaigners – NIMBYs — pose a major challenge to projects.

Petitgas, 62, retired from Morgan Stanley last year after nearly 30 years at the bank, where he led its international division from London. The issues over connections and planning have been repeatedly pointed out to Petitgas by investors and trade groups over a series of meetings this year, according to people familiar with the matter, requesting anonymity discussing private talks.

Yet with a general election looming and the issue plagued by political headaches, many are skeptical that Sunak can find the solutions needed.

One business chief said Downing Street considers the issue too tricky and expensive to tackle in the short-term. Others are concerned that while Petitgas has license from Sunak, he doesn’t have influence across the relevant departments to get grids to the top of the agenda.

 

Wind Farms

Multiple parts of the UK’s climate plans are under pressure. Earlier this month, an auction for contracts to build new wind farms received zero bids from developers, even as wind leads the power mix in many regions, marking yet another green setback. 

The UK is already behind on its target of having 50 gigawatts of offshore wind built by 2030, up from 14 GW today. The challenge is accelerating development without railroading local communities.

Within Sunak’s Conservative Party, some lawmakers are pushing back on new infrastructure in their local areas. A group including Environment Secretary Therese Coffey and former Home Secretary Priti Patel is campaigning against building new pylons across a stretch of eastern England.

According to Adam Bell, director of policy at consultancy Stonehaven, backbench pressure means Sunak is unlikely to take major action on the grid in the near term. He doesn’t see the prime minister accepting Winser’s recommendations, least of all accelerating planning decisions.

“Over the last year, Sunak has favored party management over things that will benefit the country,” Bell said. 

 

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Global: Nuclear power: what the ‘green industrial revolution’ means for the next three waves of reactors

UK Nuclear Energy Ten Point Plan outlines support for large reactors, SMRs, and AMRs, funding Sizewell C, hydrogen production, and industrial heat to reach net zero, decarbonize transport and heating, and expand clean electricity capacity.

 

Key Points

A UK plan backing large, small, and advanced reactors to drive net zero via clean power, hydrogen, and industrial heat.

✅ Funds large plants (e.g., Sizewell C) under value-for-money models

✅ Invests in SMRs for factory-built, modular, lower-cost deployment

✅ Backs AMRs for high-temperature heat, hydrogen, and industry

 

The UK government has just announced its “Ten Point Plan for a Green Industrial Revolution”, in which it lays out a vision for the future of energy, transport and nature in the UK. As researchers into nuclear energy, my colleagues and I were pleased to see the plan is rather favourable to new nuclear power.

It follows the advice from the UK’s Nuclear Innovation and Research Advisory Board, pledging to pursue large power plants based on current technology, and following that up with financial support for two further waves of reactor technology (“small” and “advanced” modular reactors).

This support is an important part of the plan to reach net-zero emissions by 2050, as in the years to come nuclear power will be crucial to decarbonising not just the electricity supply but the whole of society.

This chart helps illustrate the extent of the challenge faced:

Electricity generation is only responsible for a small percentage of UK emissions. William Bodel. Data: UK Climate Change Committee

Efforts to reduce emissions have so far only partially decarbonised the electricity generation sector. Reaching net zero will require immense effort to also decarbonise heating, transport, as well as shipping and aviation. The plan proposes investment in hydrogen production and electric vehicles to address these three areas – which will require, as advocates of nuclear beyond electricity argue, a lot more energy generation.

Nuclear is well-placed to provide a proportion of this energy. Reaching net zero will be a huge challenge, and industry leaders warn it may be unachievable without nuclear energy. So here’s what the announcement means for the three “waves” of nuclear power.

Who will pay for it?
But first a word on financing. To understand the strategy, it is important to realise that the reason there has been so little new activity in the UK’s nuclear sector since the 1990s is due to difficulty in financing. Nuclear plants are cheap to fuel and operate and last for a long time. In theory, this offsets the enormous upfront capital cost, and results in competitively priced electricity overall.

But ever since the electricity sector was privatised, governments have been averse to spending public money on power plants. This, combined with resulting higher borrowing costs and cheaper alternatives (gas power), has meant that in practice nuclear has been sidelined for two decades. While climate change offers an opportunity for a revival, these financial concerns remain.

Large nuclear
Hinkley Point C is a large nuclear station currently under construction in Somerset, England. The project is well-advanced, with its first reactor installed and due to come online in the middle of this decade. While the plant will provide around 7% of current UK electricity demand, its agreed electricity price is relatively expensive.

Under construction: Hinkley Point C. Ben Birchall/PA

The government’s new plan states: “We are pursuing large-scale new nuclear projects, subject to value-for-money.” This is likely a reference to the proposed Sizewell C in Suffolk, on which a final decision is expected soon. Sizewell C would be a copy of the Hinkley plant – building follow-up identical reactors achieves capital cost reductions, and setbacks at Hinkley Point C have sharpened delivery focus as an alternative funding model will likely be implemented to reduce financing costs.

Other potential nuclear sites such as Wylfa and Moorside (shelved in 2018 and 2019 respectively for financial reasons) are also not mentioned, their futures presumably also covered by the “subject to value-for-money” clause.

Small nuclear
The next generation of nuclear technology, with various designs under development worldwide are smaller, cheaper, safer Small Modular Reactors (SMRs), such as the Rolls Royce “UK SMR”.

Reactors small enough to be manufactured in factories and delivered as modules can be assembled on site in much shorter times than larger designs, which in contrast are constructed mostly on site. In so doing, the capital costs per unit (and therefore borrowing costs) could be significantly lower than current new-builds.

The plan states “up to £215 million” will be made available for SMRs, Phase 2 of which will begin next year, with anticipated delivery of units around a decade from now.

Advanced nuclear
The third proposed wave of nuclear will be the Advanced Modular Reactors (AMRs). These are truly innovative technologies, with a wide range of benefits over present designs and, like the small reactors, they are modular to keep prices down.

Crucially, advanced reactors operate at much higher temperatures – some promise in excess of 750°C compared to around 300°C in current reactors. This is important as that heat can be used in industrial processes which require high temperatures, such as ceramics, which they currently get through electrical heating or by directly burning fossil fuels. If those ceramics factories could instead use heat from AMRs placed nearby, it would reduce CO₂ emissions from industry (see chart above).

High temperatures can also be used to generate hydrogen, which the government’s plan recognises has the potential to replace natural gas in heating and eventually also in pioneering zero-emission vehicles, ships and aircraft. Most hydrogen is produced from natural gas, with the downside of generating CO₂ in the process. A carbon-free alternative involves splitting water using electricity (electrolysis), though this is rather inefficient. More efficient methods which require high temperatures are yet to achieve commercialisation, however if realised, this would make high temperature nuclear particularly useful.

The government is committing “up to £170 million” for AMR research, and specifies a target for a demonstrator plant by the early 2030s. The most promising candidate is likely a High Temperature Gas-cooled Reactor which is possible, if ambitious, over this timescale. The Chinese currently lead the way with this technology, and their version of this reactor concept is expected soon.

In summary, the plan is welcome news for the nuclear sector, even as Europe loses nuclear capacity across the continent. While it lacks some specifics, these may be detailed in the government’s upcoming Energy White Paper. The advice to government has been acknowledged, and the sums of money mentioned throughout are significant enough to really get started on the necessary research and development.

Achieving net zero is a vast undertaking, and recognising that nuclear can make a substantial contribution if properly supported is an important step towards hitting that target.

 

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Dubai Planning Large-Scale Solar Powered Hydrogen Production

Dubai Green Hydrogen advances electrolysis at the Mohammed Bin Rashid Al Maktoum Solar Park, with DEWA and Siemens enabling clean energy storage, re-electrification, and fuel-cell mobility for Expo 2020 Dubai and public transport.

 

Key Points

Dubai Green Hydrogen is a DEWA-Siemens project making solar hydrogen for storage, mobility, and reelectrification.

✅ Electrolysis at Mohammed Bin Rashid Al Maktoum Solar Park

✅ Partners: DEWA and Siemens; public-private demonstration plant

✅ Hydrogen for buses, re-electrification, and energy storage

 

Something you hear frequently if you are a clean tech aficionado is that excess solar and wind power can be used to split water into oxygen and hydrogen. The Dubai Supreme Council of Energy, the 2020 Dubai Higher Committee and the Dubai Electricity and Water Authority broke ground in early February on a solar power hydrogen electrolysis facility located in the Mohammed Bin Rashid Al Maktoum Solar Park, and related initiatives like the Solar Decathlon Middle East underscore Dubai's clean energy focus. Sheikh Ahmed bin Saeed Al Maktoum, chairman of the Dubai Supreme Council of Energy and chairman of the Expo 2020 Dubai Higher Committee, participated in the groundbreaking ceremony, according to a report by Khaleej Times.

Saeed Mohammed Al Tayer, CEO of DEWA, said at the groundbreaking ceremony the project is important to understanding the limits of green hydrogen technology and how it can contribute to the UAE’s vision of clean energy, and aligns with DEWA's latest renewable initiatives now progressing in the emirate. “This pioneering project is a role model for strategic partnerships between the public and private sectors. It will contribute to developing the green economy concept in the UAE and explore the potential of green hydrogen technology. The hydrogen produced at the facility will be stored and deployed for re-electrification, transportation and other uses.”

Siemens is providing much of the technology that will be used at the demonstration facility, while DEWA expands its China outreach to woo renewable energy firms that can contribute to the ecosystem. Joe Kaeser, president and CEO of Siemens, said the UAE was the perfect location for Siemens to test the technology, building on advances in offshore green hydrogen the company is pursuing. One of the primary uses of the hydrogen produced will be to power Dubai’s public transportation system.

“We are aware of the stress that is placed on vehicles in this region due to the high levels of heat; with hydrogen cells, you are not putting as much strain on the vehicle and that improves its longevity,” Kaeser said. “However, this is only the first step and we are eager to explore more ways in which we can adapt the technology to other sectors. The interest from various companies and partners has been immense and we are eager to work with all interested parties.”

“Dewa, Expo 2020 Dubai and Siemens are working together to help realize His Highness Sheikh Mohammed bin Rashid Al Maktoum, Vice-President and Prime Minister of the UAE and Ruler of Dubai’s, vision to identify new energy resources and provide sustainable power as part of a balanced approach that prioritizes the environment. Our aim is to make Dubai a model of energy efficiency and safety,” said Sheikh Ahmed.

Expo 2020 Dubai intends to use the hydrogen generated at the facility to transport visitors to the Expo 2020 Dubai and the Mohammed bin Rashid Al Maktoum Solar Park, reflecting regional momentum such as Saudi Arabia's clean energy plans over the next decade, in hydrogen fuel cell powered vehicles. Live data of the green hydrogen electrolysis will be displayed at Expo 2020 Dubai to help inform broader efforts like hydrogen hubs in the United States.

 

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