General Motors Co has signed an agreement with the U.S. government to license technology developed by the government to lower costs and improve efficiency of advanced batteries for future hybrid and electric vehicles.
GM hopes to benefit from technology developed by the Energy Department's Argonne National Laboratory in time for production runs of the next generation mainly electric plug-in Volt sedan, which the company introduced in 2010.
But the full payoff depends on productive research and the commercial popularity of the most efficient cars on American roads, which currently are a fractional sales market dominated by Asian automakers.
"We need developments to get more capable batteries," said Jon Lauckner, vice president of GM's venture's unit. "That's why we need to get working on this material now and get it on the road."
The technology for more powerful and longer-lasting charges would also give GM new flexibility for dealing with suppliers and may also one day underpin homegrown development of batteries.
U.S. automakers are far behind Asian suppliers and auto companies in battery technology as they seek to move ahead with advanced designs to satisfy government and consumer demands for more fuel-efficient vehicles.
GM currently receives its lithium-ion technology for the Volt from Korea's LG Chem. LG signed a separate licensing agreement with Argonne. LG will produce battery cells at a Michigan facility now under construction.
Permission for GM and LG to use the Argonne-developed material in lithium-ion batteries is not exclusive to those companies.
The Energy Department under President Barack Obama's directive is supporting several approaches that seek to improve advanced batteries, and has sunk more than $2 billion into developing a U.S.-based battery development effort.
A battery race of sorts has developed between U.S. companies like Massachusetts-based A123 and those in Asia, like China's BYD, of which Warren Buffett's Berkshire Hathaway owns 10 percent.
The Volt sedan is GM's early signature effort in the gasoline/electric market. GM expects to produce 10,000 Volts in 2011 and 45,000 in 2012, the company said.
Brazil ICMS Tax Cap limits state VAT on fuels, natural gas, electricity, communications, and transit, promising short-term price relief amid inflation, with federal compensation to states and potential legal challenges affecting investments and ANP auctions.
Key Points
A policy capping state VAT at 17-18 percent on fuels, electricity, and services to temper prices and inflation.
✅ Caps VAT to 17-18% on fuels, power, telecom, transit
✅ Short-term relief; medium-long term impact uncertain
✅ Federal compensation; potential court challenges, investment risk
Brazil’s congress approved a bill that limits the ICMS tax rate that state governments can charge on fuels, natural gas, electricity, communications, and public transportation.
Local lawyers told BNamericas that the measure may reduce fuel and power prices in the short term, similar to Brazil power sector relief loans seen during the pandemic, but it is unlikely to produce any major effects in the medium and long term.
In most states the ceiling was set at 17% or 18% and the federal government will pay compensation to the states for lost tax revenue until December 31, via reduced payments on debts that states owe the federal government.
The bill will become law once signed by President Jair Bolsonaro, who pushed strongly for the proposal with an eye on his struggling reelection campaign for the October presidential election. Double-digit inflation has turned into a major election issue and fuel and electricity prices have been among the main inflation drivers, as seen in EU energy-driven inflation across the bloc this year. Congress’ approval of the bill is seen by analysts as political victory for the Brazilian leader.
How much difference will it make?
Marcus Francisco, tax specialist and partner at Villemor Amaral Advogados, said that in the formation of fuel and electricity prices there are other factors, including high natural gas prices, that drive increases.
“In the case of fuels, if the barrel of oil [price] increases, automatically the final price for the consumer will go up. For electricity, on the other hand, there are several subsidies and policy choices such as Florida rejecting federal solar incentives that are part of the price and that can increase the rate [paid],” he said.
There is also a possibility that some states will take the issue to the supreme court since ICMS is a key source of revenue for them, Francisco added.
Tiago Severini, a partner at law firm Vieira Rezende, said the comparison between the revenue impact and the effective price reduction, based on the estimates made by the states and the federal government, seems disproportionate, and, as seen in Europe, rolling back European electricity prices is often tougher than it appears.
“In other words, a large tax collection impact is generated, which is quite unequal among the different states, for a not so strong price reduction,” he said.
“Due to the lack of clarity regarding the precision of the calculations involved, it’s difficult even to assess the adequacy of the offsets the federal government has been considering, and international cases such as France's new electricity pricing scheme illustrate how complex it can be to align fiscal offsets with regulatory constraints, to cover the cost it would have with the compensation for the states” Severini added.
The compensation ideas that are known so far include hiking other taxes, such as the social contribution on net profits (CSLL) that is paid by oil and gas firms focused on exploration and production.
“This can generate severe adverse effects, such as legal disputes, reduced investments in the country, and reduced attractiveness of the new auctions by [sector regulator] ANP, and costly interventions like the Texas electricity market bailout after extreme weather events,” Severini said.
Ontario Global Adjustment Charge faces constitutional scrutiny as a regulatory charge vs tax; Court of Appeal revives case over electricity pricing, feed-in tariff contracts, IESO policy, and hydro rate impacts on consumers and industry.
Key Points
A provincial electricity fee funding generator contracts, now central to a court fight over tax versus regulatory charge.
✅ Funds gap between market price and contracted generator rates
✅ At issue: regulatory charge vs tax under constitutional law
✅ Linked to feed-in tariff, IESO policy, and hydro rate hikes
Ontario’s court of appeal has decided that a constitutional challenge of a steep provincial electricity charge should get its day in court, overturning a lower-court judgment that had dismissed the legal bid.
Hamilton, Ont.-based National Steel Car Ltd. launched the challenge in 2017, saying Ontario’s so-called global adjustment charge was unconstitutional because it is a tax — not a valid regulatory charge — that was not passed by the legislature.
The global adjustment funds the difference between the province’s hourly electricity price and the price guaranteed under contracts to power generators. It is “the component that covers the cost of building new electricity infrastructure in the province, maintaining existing resources, as well as providing conservation and demand management programs,” the province’s Independent Electricity System Operator says.
However, the global adjustment now makes up most of the commodity portion of a household electricity bill, and its costs have ballooned, as regulators elsewhere consider a proposed 14% rate hike in Nova Scotia.
Ontario’s auditor general said in 2015 that global adjustment fees had increased from $650 million in 2006 to more than $7 billion in 2014. She added that consumers would pay $133 billion in global adjustment fees from 2015 to 2032, after having already paid $37 billion from 2006 to 2014.
National Steel Car, which manufactures steel rail cars and faces high electricity rates that hurt Ontario factories, said its global adjustment costs went from $207,260 in 2008 to almost $3.4 million in 2016, according to an Ontario Court of Appeal decision released on Wednesday.
The company claimed the global adjustment was a tax because one of its components funds electricity procurement contracts under a “feed-in tariff” program, or FIT, which National Steel Car called “the main culprit behind the dramatic price increases for electricity,” the decision said.
Ontario’s auditor general said the FIT program “paid excessive prices to renewable energy generators.” The program has been ended, but contracts awarded under it remain in place.
National Steel Car claimed the FIT program “was actually designed to accomplish social goals unrelated to the generation of electricity,” such as helping rural and indigenous communities, and was therefore a tax trying to help with policy goals.
“The appellant submits that the Policy Goals can be achieved by Ontario in several ways, just not through the electricity pricing formula,” the decision said.
National Steel Car also argued the global adjustment violated a provincial law that requires the government to hold a referendum for new taxes.
“The appellant’s principal claim is that the Global Adjustment was a ‘colourable attempt to disguise a tax as a regulatory charge with the purpose of funding the costs of the Policy Goals,’” the decision said. “The appellant pressed this argument before the motion judge and before this court. The motion judge did not directly or adequately address it.”
The Ontario government applied to have the challenge thrown out for having “no reasonable cause of action,” and a Superior Court judge did so in 2018, saying the global adjustment is not a tax.
National Steel Car appealed the decision, and the decision published Wednesday allowed the appeal, set aside the lower-court judgment, and will send the case back to Superior Court, where it could get a full hearing.
“The appellant’s claim is sufficiently plausible on the evidentiary record it put forward that the applications should not have been dismissed on a pleadings motion before the development of a full record,” wrote Justice Peter D. Lauwers. “It is not plain, obvious and beyond doubt that the Global Adjustment, and particularly the challenged component, is properly characterized as a valid regulatory charge and not as an impermissible tax.”
Jerome Morse of Morse Shannon LLP, one of National Steel Car’s lawyers, said the Ontario government would now have 60 days to decide whether to seek permission to appeal to the Supreme Court of Canada.
“What the court has basically said is, ‘this is a plausible argument, here are the reasons why it’s plausible, there was no answer to this,’” Morse told the Financial Post.
Ontario and the IESO had supported the lower-court decision, but there has been a change in government since the challenge was first launched, with Progressive Conservative Premier Doug Ford replacing the Liberals and Kathleen Wynne in power. The Liberals had launched a plan aimed at addressing hydro costs before losing in a 2018 election, the main thrust of which had been to refinance global adjustment costs.
Wednesday’s decision states that “Ontario’s counsel advised the court that the current Ontario government ‘does not agree with the former government’s electricity procurement policy (since-repealed).’
“The government’s view is that: ‘The solution does not lie with the courts, but instead in the political arena with political actors,’” it adds.
A spokesperson for Ontario Energy Minister Greg Rickford said in an email that they are reviewing the decision but “as this matter is in the appeal period, it would be inappropriate to comment.”
Ontario had also requested to stay the matter so a regulator, the Ontario Energy Board, could weigh in, while the Nova Scotia regulator approved a 14% hike in a separate case.
“However, Ontario only sought this relief from the motion judge in the alternative, and given the motion judge’s ultimate decision, she did not rule on the stay,” Thursday’s decision said. “It would be premature for this court to rule on the issue, although it seems incongruous for Ontario to argue that the Superior Court is the convenient forum in which to seek to dismiss the applications as meritless, but that it is not the convenient forum for assessing the merits of the applications.”
National Steel Car’s challenge bears a resemblance to the constitutional challenges launched by Ontario and other provinces over the federal government’s carbon tax, but Justice Lauwers wrote “that the federal legislative scheme under consideration in those cases is distinctly different from the legislation at issue in this appeal.”
“Nothing in those decisions impacts this appeal,” the judge added.
Newfoundland and Labrador electricity rate hike examines a proposed 18.6% increase under the PUB's Rate Stabilization Plan, driven by oil prices at Holyrood, with Consumer Advocate concerns over rate shock and use of RSP balances.
Key Points
A proposed 18.6% July 2017 increase under the RSP, driven by oil prices, now under PUB review for potential mitigation.
✅ PUB flags potential rate shock from proposed adjustment
✅ RSP balances cited to offset increases without depleting fund
How much of a rate hike is reasonable for users of electricity in Newfoundland and Labrador?
That's a question before the Public Utilities Board (PUB) as it examines an application by Newfoundland and Labrador Hydro, which could see consumers pay up to 18.6 per cent more as of July 1, reflecting regional pressures seen in Nova Scotia, where regulators approved a 14% rate hike earlier this year.
"The estimated rate increase for July 2017 is such a significant increase that it may be argued that it would cause rate shock," said the PUB, asking the company to revise its application.
NL Hydro said the price adjustment is part of what happens every year through the Rate Stabilization Plan (RSP), which is used to offset the ups and downs of oil prices.
"The cost of fuel is volatile and as long as we rely on oil-fired generation at Holyrood, customers will continue to be impacted by this electricity price uncertainty," said the company in a statement to CBC News.
It noted that customers received a break from RSP adjustments in 2015 and 2016, even as costs from the Muskrat Falls project begin to be reflected.
The PUB noted that under the rate stabilization plan, prices have gone up or down by about 10 per cent in the past.
The regulatory board said the impact of the latest request would be a 27.6 per cent hike to Newfoundland Power, with "an estimated average end customer impact of 18.6 per cent."
Hydro's estimates are based on an average price for oil of $81.40 per barrel from July 2017 to June 2018, according to the PUB.
'Unacceptable' burden: Consumer Advocate
"To burden ratepayers with an 18 per cent rate increase is unacceptable," said Consumer Advocate Dennis Browne, echoing pushback in Nova Scotia, where the premier urged regulators to reject a 14% hike at the time.
Browne is arguing that there is money in the RSP to reduce the proposed increase, including the possibility of a lump-sum bill credit for customers.
"These ratepayer balances — which, according to NL Power, totals $77.4 million — are not the property of Hydro," he wrote in a letter to the PUB.
"No utility has the right to squirrel away ratepayers' money to be used by that utility for some future purpose. The Board has jurisdiction over those balances," Browne said.
Browne also wants the RSP overhauled so that it can be applied to price fluctuations every quarter, as opposed to annually.
Hydro has expressed concern that depleting the rate stabilization fund would lead to other, more significant, rate increases in the future.
It said several alternatives to mitigate high rates have been provided to the PUB, which has final say, similar to how Manitoba Hydro scaled back a planned increase in the next year.
Advanced Nuclear Reactors drive U.S. clean energy with small modular reactors, a new test facility at Idaho National Laboratory, and public-private partnerships accelerating nuclear innovation, safety, and cost reductions through DOE-backed programs and university simulators.
Key Points
Advanced nuclear reactors are next-gen designs, including SMRs, offering safer, cheaper, low-carbon power.
✅ DOE test facility at Idaho National Laboratory
✅ Small modular reactors with passive safety systems
✅ University simulators train next-gen nuclear operators
Energy Secretary Rick Perry is advancing plans to shift the United States towards next-gen nuclear power reactors.
The Energy Department announced this week it has launched a new test facility at the Idaho National Laboratory where private companies can work on advanced nuclear technologies, as the first new U.S. reactor in nearly seven years starts up, to avoid the high costs and waste and safety concerns facing traditional nuclear power plants.
“[The National Reactor Innovation Center] will enable the demonstration and deployment of advanced reactors that will define the future of nuclear energy,” Perry said.
With climate change concerns growing and net-zero emissions targets emerging, some Republicans and Democrats are arguing for the need for more nuclear reactors to feed the nation’s electricity demand. But despite nuclear plants’ absence of carbon emissions, the high cost of construction, questions around what to do with the spent nuclear rods and the possibility of meltdown have stymied efforts.
A new generation of firms, including Microsoft founder Bill Gates’ Terra Power venture, are working on developing smaller, less expensive reactors that do not carry a risk of meltdown.
“The U.S. is on the verge of commercializing groundbreaking nuclear innovation, and we must keep advancing the public-private partnerships needed to traverse the dreaded valley of death that all too often stifles progress,” said Rich Powell, executive director of ClearPath, a non-profit advocating for clean energy and green industrial strategies worldwide.
The new Idaho facility is budgeted at $5 million under next year’s federal budget, even as the cost of U.S. nuclear generation has fallen to a ten-year low, which remains under negotiation in Congress.
On Thursday another advanced nuclear developer working on small modular systems, Oregon-based NuScale Power, announced it was building three virtual nuclear control rooms at Texas A&M University, Oregon State University and the University of Idaho, with funding from the Energy Department.
The simulators will be open to researchers and students, to train on the operation of smaller, modular reactors, as well as the general public.
NuScale CEO John Hopkins said the simulators would “help ensure that we educate future generations about the important role nuclear power and small modular reactor technology will play in attaining a safe, clean and secure energy future for our country.”
Ontario Clean Electricity Regulations accelerate renewable energy adoption, drive emissions reduction, and modernize the smart grid with energy storage, efficiency targets, and reliability upgrades to support decarbonization and a stable power system for Ontario.
Key Points
Standards to cut emissions, grow renewables, improve efficiency, and modernize the grid with storage and smart systems.
✅ Phases down fossil generation and invests in storage.
✅ Sets utility efficiency targets to curb demand growth.
✅ Upgrades to smart grid for reliability and resiliency.
Ontario has taken a significant step forward in its energy transition with the introduction of new clean electricity regulations. These regulations, complementing federal Clean Electricity Regulations, aim to reduce carbon emissions, promote sustainable energy sources, and ensure a cleaner, more reliable electricity grid for future generations. This article explores the motivations behind these regulations, the strategies being implemented, and the expected impacts on Ontario’s energy landscape.
The Need for Clean Electricity
Ontario, like many regions around the world, is grappling with the effects of climate change, including more frequent and severe weather events. In response, the province has set ambitious targets to reduce greenhouse gas emissions and increase the use of renewable energy sources, reflecting trends seen in Alberta’s path to clean electricity across Canada. The electricity sector plays a central role in this transition, as it is responsible for a significant portion of the province’s carbon footprint.
For years, Ontario has been moving away from coal as a source of electricity generation, and now, with the introduction of these new regulations, the province is taking a step further in decarbonizing its grid, including its largest competitive energy procurement to date. By setting clear goals and standards for clean electricity, the province hopes to meet its environmental targets while ensuring a stable and affordable energy supply for all Ontarians.
Key Aspects of the New Regulations
The regulations focus on encouraging the use of renewable energy sources such as wind, solar, hydroelectric, and geothermal power. One of the key elements of the plan is the gradual phase-out of fossil fuel-based energy sources. This shift is expected to be accompanied by greater investments in energy storage solutions, including grid batteries, to address the intermittency issues often associated with renewable energy sources.
Ontario’s new regulations also emphasize the importance of energy efficiency in reducing overall demand. As part of this initiative, utilities and energy providers will be required to meet strict energy-saving targets and participate in new electricity auctions designed to reduce costs, ensuring that both consumers and businesses are incentivized to use energy more efficiently.
In addition, the regulations promote technological innovation in the electricity sector. By supporting the development of smart grids, energy storage technologies, and advanced power management systems, Ontario is positioning itself to become a leader in the global energy transition.
Impact on the Economy and Jobs
One of the anticipated benefits of the clean electricity regulations is their positive impact on Ontario’s economy. As the province invests in renewable energy infrastructure and clean technologies, new job opportunities are expected to arise in industries such as manufacturing, construction, and research and development. These regulations also encourage innovation in energy services, which could lead to the growth of new companies and industries, while easing pressures on industrial ratepayers through complementary measures.
Furthermore, the transition to cleaner energy is expected to reduce the long-term costs associated with climate change. By investing in sustainable energy solutions now, Ontario will help mitigate the financial burdens of environmental damage and extreme weather events in the future.
Challenges and Concerns
While the new regulations have been widely praised for their environmental benefits, they are not without their challenges. One of the primary concerns is the potential cost to consumers, and some Ontario hydro policy critique has called for revisiting legacy pricing approaches to improve affordability. While renewable energy sources have become more affordable over the years, transitioning from fossil fuels could still result in higher electricity prices in the short term. Additionally, the implementation of new technologies, such as smart grids and energy storage, will require substantial upfront investment.
Moreover, the intermittency of renewable energy generation poses a challenge to grid stability. Ontario’s electricity grid must be able to adapt to fluctuations in energy supply as more variable renewable sources come online. This challenge will require significant upgrades to the grid infrastructure and the integration of storage solutions to ensure reliable energy delivery.
The Road Ahead
Ontario’s clean electricity regulations represent an important step in the province’s commitment to combating climate change and transitioning to a sustainable, low-carbon economy. While there are challenges to overcome, the benefits of cleaner air, reduced emissions, and a more resilient energy system will be felt for generations to come. As the province continues to innovate and lead in the energy sector, Ontario is positioning itself to thrive in the green economy of the future.
ITER Nuclear Fusion advances tokamak magnetic confinement, heating deuterium-tritium plasma with superconducting magnets, targeting net energy gain, tritium breeding, and steam-turbine power, while complementing laser inertial confinement milestones for grid-scale electricity and 2025 startup goals.
Key Points
ITER Nuclear Fusion is a tokamak project confining D-T plasma with magnets to achieve net energy gain and clean power.
✅ Tokamak magnetic confinement with high-temp superconducting coils
✅ Deuterium-tritium fuel cycle with on-site tritium breeding
✅ Targets net energy gain and grid-scale, low-carbon electricity
It sounds like the stuff of dreams: a virtually limitless source of energy that doesn’t produce greenhouse gases or radioactive waste. That’s the promise of nuclear fusion, often described as the holy grail of clean energy by proponents, which for decades has been nothing more than a fantasy due to insurmountable technical challenges. But things are heating up in what has turned into a race to create what amounts to an artificial sun here on Earth, one that can provide power for our kettles, cars and light bulbs.
Today’s nuclear power plants create electricity through nuclear fission, in which atoms are split, with next-gen nuclear power exploring smaller, cheaper, safer designs that remain distinct from fusion. Nuclear fusion however, involves combining atomic nuclei to release energy. It’s the same reaction that’s taking place at the Sun’s core. But overcoming the natural repulsion between atomic nuclei and maintaining the right conditions for fusion to occur isn’t straightforward. And doing so in a way that produces more energy than the reaction consumes has been beyond the grasp of the finest minds in physics for decades.
But perhaps not for much longer. Some major technical challenges have been overcome in the past few years and governments around the world have been pouring money into fusion power research as part of a broader green industrial revolution under way in several regions. There are also over 20 private ventures in the UK, US, Europe, China and Australia vying to be the first to make fusion energy production a reality.
“People are saying, ‘If it really is the ultimate solution, let’s find out whether it works or not,’” says Dr Tim Luce, head of science and operation at the International Thermonuclear Experimental Reactor (ITER), being built in southeast France. ITER is the biggest throw of the fusion dice yet.
Its $22bn (£15.9bn) build cost is being met by the governments of two-thirds of the world’s population, including the EU, the US, China and Russia, at a time when Europe is losing nuclear power and needs energy, and when it’s fired up in 2025 it’ll be the world’s largest fusion reactor. If it works, ITER will transform fusion power from being the stuff of dreams into a viable energy source.
Constructing a nuclear fusion reactor ITER will be a tokamak reactor – thought to be the best hope for fusion power. Inside a tokamak, a gas, often a hydrogen isotope called deuterium, is subjected to intense heat and pressure, forcing electrons out of the atoms. This creates a plasma – a superheated, ionised gas – that has to be contained by intense magnetic fields.
The containment is vital, as no material on Earth could withstand the intense heat (100,000,000°C and above) that the plasma has to reach so that fusion can begin. It’s close to 10 times the heat at the Sun’s core, and temperatures like that are needed in a tokamak because the gravitational pressure within the Sun can’t be recreated.
When atomic nuclei do start to fuse, vast amounts of energy are released. While the experimental reactors currently in operation release that energy as heat, in a fusion reactor power plant, the heat would be used to produce steam that would drive turbines to generate electricity, even as some envision nuclear beyond electricity for industrial heat and fuels.
Tokamaks aren’t the only fusion reactors being tried. Another type of reactor uses lasers to heat and compress a hydrogen fuel to initiate fusion. In August 2021, one such device at the National Ignition Facility, at the Lawrence Livermore National Laboratory in California, generated 1.35 megajoules of energy. This record-breaking figure brings fusion power a step closer to net energy gain, but most hopes are still pinned on tokamak reactors rather than lasers.
In June 2021, China’s Experimental Advanced Superconducting Tokamak (EAST) reactor maintained a plasma for 101 seconds at 120,000,000°C. Before that, the record was 20 seconds. Ultimately, a fusion reactor would need to sustain the plasma indefinitely – or at least for eight-hour ‘pulses’ during periods of peak electricity demand.
A real game-changer for tokamaks has been the magnets used to produce the magnetic field. “We know how to make magnets that generate a very high magnetic field from copper or other kinds of metal, but you would pay a fortune for the electricity. It wouldn’t be a net energy gain from the plant,” says Luce.
One route for nuclear fusion is to use atoms of deuterium and tritium, both isotopes of hydrogen. They fuse under incredible heat and pressure, and the resulting products release energy as heat
The solution is to use high-temperature, superconducting magnets made from superconducting wire, or ‘tape’, that has no electrical resistance. These magnets can create intense magnetic fields and don’t lose energy as heat.
“High temperature superconductivity has been known about for 35 years. But the manufacturing capability to make tape in the lengths that would be required to make a reasonable fusion coil has just recently been developed,” says Luce. One of ITER’s magnets, the central solenoid, will produce a field of 13 tesla – 280,000 times Earth’s magnetic field.
The inner walls of ITER’s vacuum vessel, where the fusion will occur, will be lined with beryllium, a metal that won’t contaminate the plasma much if they touch. At the bottom is the divertor that will keep the temperature inside the reactor under control.
“The heat load on the divertor can be as large as in a rocket nozzle,” says Luce. “Rocket nozzles work because you can get into orbit within minutes and in space it’s really cold.” In a fusion reactor, a divertor would need to withstand this heat indefinitely and at ITER they’ll be testing one made out of tungsten.
Meanwhile, in the US, the National Spherical Torus Experiment – Upgrade (NSTX-U) fusion reactor will be fired up in the autumn of 2022, while efforts in advanced fission such as a mini-reactor design are also progressing. One of its priorities will be to see whether lining the reactor with lithium helps to keep the plasma stable.
Choosing a fuel Instead of just using deuterium as the fusion fuel, ITER will use deuterium mixed with tritium, another hydrogen isotope. The deuterium-tritium blend offers the best chance of getting significantly more power out than is put in. Proponents of fusion power say one reason the technology is safe is that the fuel needs to be constantly fed into the reactor to keep fusion happening, making a runaway reaction impossible.
Deuterium can be extracted from seawater, so there’s a virtually limitless supply of it. But only 20kg of tritium are thought to exist worldwide, so fusion power plants will have to produce it (ITER will develop technology to ‘breed’ tritium). While some radioactive waste will be produced in a fusion plant, it’ll have a lifetime of around 100 years, rather than the thousands of years from fission.
At the time of writing in September, researchers at the Joint European Torus (JET) fusion reactor in Oxfordshire were due to start their deuterium-tritium fusion reactions. “JET will help ITER prepare a choice of machine parameters to optimise the fusion power,” says Dr Joelle Mailloux, one of the scientific programme leaders at JET. These parameters will include finding the best combination of deuterium and tritium, and establishing how the current is increased in the magnets before fusion starts.
The groundwork laid down at JET should accelerate ITER’s efforts to accomplish net energy gain. ITER will produce ‘first plasma’ in December 2025 and be cranked up to full power over the following decade. Its plasma temperature will reach 150,000,000°C and its target is to produce 500 megawatts of fusion power for every 50 megawatts of input heating power.
“If ITER is successful, it’ll eliminate most, if not all, doubts about the science and liberate money for technology development,” says Luce. That technology development will be demonstration fusion power plants that actually produce electricity, where advanced reactors can build on decades of expertise. “ITER is opening the door and saying, yeah, this works – the science is there.”
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