Miniature reactors seek approval to work in U.S.

By Business Week


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Manufacturers of refrigerator-sized nuclear reactors will seek approval from U.S. authorities within a year to help supply the worldÂ’s growing electricity demand.

John Deal, chief executive officer of Hyperion Power Generation Inc., intends to apply for a license “within a year” for plants that would power a small factory or town too remote for traditional utility grid connections.

The Santa Fe, New Mexico-based company and JapanÂ’s Toshiba Corp. are vying for a head start over reactor makers General Electric Co. and Areva SA in downsizing nuclear technology and aim to submit license applications in the next year to U.S. regulators. TheyÂ’re seeking to tap a market that has generated about $135 billion in pending orders for large nuclear plants.

“We’re building iPhones when the nuclear industry has traditionally built mainframe computers,” said Deal. Hyperion has more than 150 purchase commitments from customers such as mining and telecom companies, provided its technology gets licensed for operation, he said.

A generation after the Chernobyl and Three Mile Island accidents wiped reactor construction off the agenda of many governments, developers are pressing ahead with designs to satisfy demand for power that doesnÂ’t pollute the skies.

World electricity demand is likely to grow 2.7 percent a year from now until 2015 and then 2.4 percent annually until 2030, the International Energy Association estimates.

While utility-scale reactors cost about $2.3 billion apiece and produce 1.2 gigawatts of power, HyperionÂ’s price tag is $50 million for a 25-megawatt reactor more comparable to a diesel generators or wind farms.

Transportable by truck, the units would come in a sealed box and work around the clock, requiring less maintenance than a fossil fuel plant, the developers say. TheyÂ’d cost 15 percent less per megawatt of capacity than the average full-scale atomic reactors now in on the drawing board, according to World Nuclear Association data.

“A 25-megawatt plant would put electricity into 20,000 homes, and it would fit inside this room,” James Kohlhaas, vice president at a Lockheed Martin Corp. unit that builds power systems for remote military bases, said in an interview. “It’s a pretty elegant micro-grid solution.”

Certifying and building small reactors will require the same multi-year licensing procedure necessary for bigger plants. And since no small-scale systems are operating, thereÂ’s no track record to know how well they will work.

“Whether it’s a small or large reactor, the hoops you have to jump through are the same,” said Hans-Holger Rogner, head of economic planning at the International Atomic Energy Agency. “You open up a Pandora’s Box of intervention from society every time you try to build any kind of nuclear plant.”

Environmentalists are concerned the small reactors would pose the same risk of leaking radioactive materials as their larger counterparts, said Jan Beranek, nuclear energy project leader at Greenpeace International in Amsterdam.

“Terrorists could hijack a reactor and directly use it to cause a meltdown or use it to fabricate fissile materials for later use in a weapon,” Beranek said.

Deal rejects those concerns, noting his units are designed to fit in the same canisters used to transport nuclear fuel for bigger plants around the world. The power-producing core of HyperionÂ’s reactor comes in multiple sealed chambers, which would contain any leak. The entire unit would be installed in an underground vault to protect it from tampering and natural threats, the company says.

“You still have to have guards and dogs, but you have to do that with a grocery store in some countries,” Deal said.

So far, no manufacturer has sought certification for any small reactor, according to the U.S. Nuclear Regulatory Commission. Formal approvals would probably take three to five years, the same as for bigger reactors, said Scott Burnell, a spokesman for the commission.

Small reactors have been used in U.S. submarines since the USS Nautilus was commissioned in 1954. RussiaÂ’s Rosatom Corp. is using its experience on submarines and icebreakers to develop atomic plants for floating barges.

HyperionÂ’s technology was invented at the U.S. governmentÂ’s Los Alamos National Laboratory in New Mexico. Six other reactor designs are in information-sharing stages, including ones from NuScale Power Inc., Toshiba and its Westinghouse unit.

Westinghouse has been developing small reactors since 1999, imagining customers in “lesser developed” countries and from small industry and utilities, Michael Anness, manager of the company’s Advanced Reactors, Research and Technology division, said in an e-mailed response to questions.

Toshiba, based in Tokyo, is working on reactors that would produce 10 megawatts and 50 megawatts, called 4S for “super- safe, small and simple.” It will apply later this year for U.S. approval to test the unit in the village of Galena in central Alaska, said company spokesman Keisuke Ohmori.

Galena has no connection to power lines and is closed to barge traffic for supplies for more than half the year when the Yukon River freezes. To provide heat and electricity, the town relies on diesel fuel, whose price has risen by about 48 percent in the past 12 months.

“We aim to get 4S orders in remote areas where it is more cost-efficient to generate power on a local basis than use power grids,” Ohmori said. “A great many people are interested.”

Both Toshiba and Hyperion are designing reactors that would run about five times longer without servicing than the 18 to 24 months typical at utility plants.

Toshiba signed an agreement in November with TerraPower, controlled by Microsoft Corp. founder Bill Gates, to exchange design and engineering know-how. In February Gates said a small-scale pilot project needed “several billion” dollars. Deal, a licensed Christian minister and self-confessed “left-wing nutbag” who only began to support nuclear power four years ago, says the simplicity and scale of his reactor can overcome concerns about waste and terrorism.

“Attitudes change,” said Deal, 46, who’s working at his sixth start-up company in 20 years after previous roles at spy satellite technology and wind power businesses. “There’s not a lot of people out there railing against nuclear power.”

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Michigan Public Service Commission grants Consumers Energy request for more wind generation

Consumers Energy Wind Expansion gains MPSC approval in Michigan, adding up to 525 MW of wind power, including Gratiot Farms, while solar capacity requests face delays over cost projections under the renewable portfolio standard targets.

 

Key Points

A regulatory-approved plan enabling Consumers Energy to add 525 MW of wind while solar additions await cost review.

✅ MPSC approves up to 525 MW in new wind projects

✅ Gratiot Farms purchase allowed before May 1

✅ Solar request delayed over high cost projections

 

Consumers Energy Co.’s efforts to expand its renewable offerings gained some traction this week when the Michigan Public Service Commission (MPSC) approved a request for additional wind generation capacity.

Consumers had argued that both more wind and solar facilities are needed to meet the state’s renewable portfolio standard, which was expanded in 2016 to encompass 12.5 percent of the retail power of each Michigan electric provider. Those figures will continue to rise under the law through 2021 when the figure reaches 15 percent, alongside ongoing electricity market reforms discussions. However, Consumers’ request for additional solar facilities was delayed at this time due to what the Commission labeled unrealistically high-cost projections.

Consumers will be able to add as much as 525 megawatts of new wind projects amid a shifting wind market, including two proposed 175-megawatt wind projects slated to begin operation this year and next. Consumers has also been allowed to purchase the Gratiot Farms Wind Project before May 1.

The MPSC said a final determination would be made on Consumers’ solar requests during a decision in April. Consumers had sought an additional 100 megawatts of solar facilities, hoping to get them online sometime in 2024 and 2025.

 

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Clean, affordable electricity should be an issue in the Ontario election

Ontario Electricity Supply Gap threatens growth as demand from EVs, heat pumps, industry, and greenhouses surges, pressuring the grid and IESO to add nuclear, renewables, storage, transmission, and imports while meeting net-zero goals.

 

Key Points

The mismatch as Ontario's electricity demand outpaces supply, driven by electrification, EVs, and industrial growth.

✅ Demand growth from EVs, heat pumps, and electrified industry

✅ Capacity loss from Pickering retirement and Darlington refurb

✅ Options: SMRs, renewables, storage, conservation, imports

 

Ontario electricity demand is forecast to soon outstrip supply as it confronts a shortage in the coming years, a problem that needs attention in the upcoming provincial election.

Forecasters say Ontario will need to double its power supply by 2050 as industries ramp up demand for low-emission clean power options and consumers switch to electric vehicles and space heating. But while the Ford government has made a flurry of recent energy announcements, including a hydrogen project at Niagara Falls and an interprovincial agreement on small nuclear reactors, it has not laid out how it intends to bulk up the province’s power supply.

“Ontario is entering a period of widening electricity shortfalls,” says the Ontario Chamber of Commerce. “Having a plan to address those shortfalls is essential to ensure businesses can continue investing and growing in Ontario with confidence.”

The supply and demand mismatch is coming because of brisk economic growth combined with increasing electrification to balance demand and emissions and meet Canada’s goal to reduce CO2 emissions by 40 per cent by 2030 and to net-zero by 2050.

Hamilton’s ArcelorMittal Dofasco and Algoma Steel in Sault Ste. Marie are leaders on this transformation. They plan to replace their blast furnaces and basic oxygen furnaces later this decade with electric arc furnaces (EAFs), reducing annual CO2 emissions by three million tonnes each.


Dofasco, which operates an EAF that is already the single largest electricity user in Ontario, plans to build a second EAF and a gas-fired ironmaking furnace, which can also be powered with zero-carbon hydrogen produced from electricity, once it becomes available.

Other new projects in the agriculture, mining and manufacturing sectors are also expected to be big power users, including the recently announced $5 billion Stellantis-LG electric vehicle battery plant in Windsor. Five new transmission lines will be built to service the plant and the burgeoning greenhouse industry in southwestern Ontario. The greenhouses alone will require enough additional electricity to power a city the size of Ottawa.

On top of these demands, growing numbers of Ontario drivers are expected to switch to electric vehicles and many homeowners and business owners are expected to convert from gas heating to heat pumps and electric heating.

Ontario is recognized as one of the cleanest electricity systems in the world, with over 90 per cent of its capacity from low-emission nuclear, hydro, wind and other renewable generation. Only nine per cent comes from CO2-emitting gas plants. But that’s about to get dirtier according to analysts.

Annual electricity demand is expected to grow from 140 terawatt hours (a terawatt hour is one trillion watts for one hour) currently to about 200 terawatt hours in 2042, according to the Independent Electricity System Operator, the agency that manages Ontario’s grid.

Demand is expected to outstrip currently contracted supply in 2026, reaching a growing supply gap of about 80 terawatt hours by 2042. A big part of this gap is due to the scheduled retirement of the Pickering nuclear station in 2025 and the current refurbishment of the Darlington nuclear station reactors. While the IESO doesn’t expect blackouts or brownouts, it forecasts the province will need to sharply increase expensive power imports and triple the amount of CO2-polluting gas-fired generation.

Without cleaner, lower-cost alternatives, this will mean “a vastly dirtier and more expensive electricity system,” York University researchers Mark Winfield and Collen Kaiser said in a recent commentary.

The party that wins the provincial election will have to make hard decisions on renewable energy, including new wind and solar projects, energy conservation, battery storage, new hydro plants, small nuclear reactors, gas generation and power imports from the U.S. and Quebec. In addition, the federal government is pressing the provinces to meet a new net-zero clean electricity standard by 2035. These decisions will have huge impact on Ontario’s future, with greening the grid costs highlighted in some reports as potentially very high.

With so much at stake, Ontario’s political parties need to tell voters during the upcoming campaign how they would address these enormous challenges.

 

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Michigan utilities propose more than $20M in EV charging programs

Michigan EV time-of-use charging helps DTE Energy and Consumers Energy manage off-peak demand, expand smart charger rebates, and build DC fast charging infrastructure, lowering grid costs, emissions, and peak load impacts across Michigan's distribution networks.

 

Key Points

Michigan utility programs using time-based EV rates to shift charging off-peak and ease grid load via charger rebates.

✅ Off-peak rates cut peak load and distribution transformer stress.

✅ Rebates support home smart chargers and DC fast charging sites.

✅ DTE Energy and Consumers Energy invest to expand EV infrastructure.

 

The two largest utilities in the state of Michigan, DTE Energy and Consumers Energy, are looking at time-of-use charging rates in two proposed electric vehicle (EV) charging programs, aligned with broader EV charging infrastructure trends among utilities, worth a combined $20.5 million of investments.

DTE Energy last month proposed a $13 million electric vehicle (EV) charging program, which would include transformer upgrades/additions, service drops, labor and contractor costs, materials, hardware and new meters to provide time-of-use charging rates amid evolving charging control dynamics in the market. The Charging Forward program aims to address customer education and outreach, residential smart charger support and charging infrastructure enablement, DTE told regulators in its 1,100-page filing. The utility requested that rebates provided through the program be deferred as a regulatory asset.

Consumers Energy in 2017 withdrew a proposal to install 800 electric vehicle charging ports in its Michigan service territory after questions were raised over how to pay for the $15 million plan. According to Energy News Network, the utility has filed a modified proposal building on the former plan and conversations over the last year that calls for approximately half of the original investment.

Utilities across the country are viewing new demand from EVs as a potential boon to their systems, a shift accelerated by the Model 3's impact on utility planning, potentially allowing greater utilization and lower costs. But that will require the vehicles to be plugged in when other demand is low, to avoid the need for extensive upgrades and more expensive power purchases. Michigan utilities' proposal focuses on off-peak EV charging, as well as on developing new EV infrastructure.

While adoption has remained relatively low nationally, last year the Edison Electric Institute and the Institute for Electric Innovation forecast 7 million EVs on United States' roads by the end of 2025. But unless those EVs can be coordinated, state power grids could face increased stress, the National Renewable Energy Laboratory has said distribution transformers may need to be replaced more frequently and peak load could push system limits — even with just one or two EVs on a neighborhood circuit. 

In its application, DTE told regulators that electrification of transportation offers a range of benefits including "reduced operating costs for EV drivers and affordability benefits for utility customers."

"Most EV charging takes place overnight at home, effectively utilizing distribution and generation capacity in the system during a low load period," the utility said. "Therefore, increased EV adoption puts downward pressure on rates by spreading fixed costs over a greater volume of electric sales."

DTE added that other benefits include reduced carbon emissions, improved air quality, increased expenditures in local economies and reduced dependency on foreign oil for the public at large.

A previous proposal from Consumers Energy included 60 fast charging DC stations along major highways in the Lower Peninsula and 750 240-volt AC stations in metropolitan areas. Consumers' new plan will offer rebates for charger installation, as U.S. charging networks jostle for position amid federal electrification efforts, including residential and DC fast-charging stations.

 

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Cyprus can’t delay joining the electricity highway

Cyprus Electricity Interconnectors link the island to the EU grid via EuroAsia and EuroAfrica projects, enabling renewable energy trade, subsea transmission, market liberalization, and stronger energy security and diplomacy across the region.

 

Key Points

Subsea links connecting Cyprus to Greece, Israel and Egypt for EU grid integration, renewable trade and energy security.

✅ Connects EU, Israel, Egypt via EuroAsia and EuroAfrica

✅ Enables renewables integration and market liberalization

✅ Strengthens energy security, investment, and diplomacy

 

Electricity interconnectors bridging Cyprus with the broader geographical region, mirroring projects like the Ireland-France grid link already underway in Europe, are crucial for its diplomacy while improving its game to become a clean energy hub.

In an interview with Phileleftheros daily, Andreas Poullikkas, chairman of the Cyprus Energy Regulatory Authority (CERA), said electricity cables such as the EuroAsia Interconnector and the EuroAfrica Interconnector, could turn the island into an energy hub, creating investment opportunities.

“Cyprus, with proper planning, can make the most of its energy potential, turning Cyprus into an electricity producer-state and hub by establishing electrical interconnections, such as the EuroAsia Interconnector and the EuroAfrica Interconnector,” said Poullikkas.

He said these electricity interconnectors, “will enable the island to become a hub for electricity transmission between the European Union, Israel and Egypt, with developments such as the Israel Electric Corporation settlement highlighting regional dynamics, while increasing our energy security”.

Poullikkas argued it will have beneficial consequences in shaping healthy conditions for liberalising the country’s electricity market and economy, facilitating the production of electricity with Renewable Energy Sources and supporting broader efforts like the UK grid transformation toward net zero.

“Electricity interconnections are an excellent opportunity for greater business flexibility in Cyprus, ushering new investment opportunities, as seen with the Lake Erie Connector investment across North America, either in electricity generation or other sectors. Especially at a time when any investment or financial opportunity is welcomed.”

He said Cyprus’ energy resources are a combination of hydrocarbon deposits and renewable energy sources, such as solar.

This combination offers the country a comparative advantage in the energy sector.

Cyprus can take advantage of the development of alternative supply routes of the EU, as more links such as new UK interconnectors come online.

Poullikkas argued that as energy networks are developing rapidly throughout the bloc, serving the ever-increasing needs for electricity, and aligning with the global energy interconnection vision highlighted in recent assessments, the need to connect Cyprus with its wider geographical area is a matter of urgency.

He argues the development of important energy infrastructure, especially electricity interconnections, is an important catalyst in the implementation of Cyprus goals, while recognising how rule changes like Australia's big battery market shift can affect storage strategies.

“It should also be a national political priority, as this will help strengthen diplomatic relations,” added Poullikkas.

Implementing the electricity interconnectors between Israel, Cyprus and Greece through Crete and Attica (EuroAsia Interconnector) has been delayed by two years.

He said the delay was brought about after Greece decided to separate the Crete-Attica section of the interconnection and treat as a national project.

Poullikkas stressed the Greek authorities are committed to ensuring the connection of Cyprus with the electricity market of the EU.

“All the required permits have been obtained from the competent authorities in Cyprus and upon the completion of the procedures with the preferred manufacturers, construction of the Cyprus-Crete electrical interconnection will begin before the end of this year. Based on current data, the entire interconnection is expected to be implemented in 2023”.

“The EuroAfrica Interconnector is in the pre-works stage, all project implementation studies have already been completed and submitted to the competent authorities, including cost and benefit studies”.

EuroAsia Interconnector is a leading EU project of common interest (PCI), also labelled as an “electricity highway” by the European Commission.

It connects the national grids of Israel, Cyprus and Greece, creating a reliable energy bridge between the continents of Asia and Europe allowing bi-directional transmission of electricity.

The cost of the entire subsea cable system, at 1,208km, the longest in the world and the deepest at 3,000m below sea level, is estimated at €2.5 bln.

Construction costs for the first phase of the Egypt-Cyprus interconnection (EuroAfrica) with a Stage 1 transmission capacity of 1,000MW is estimated at €1bln.

The Cyprus-Greece (Crete) interconnection, as well as the Egypt-Cyprus electricity interconnector, will both be commissioned by December 2023.

 

 

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Ontario Provides Stable Electricity Pricing for Industrial and Commercial Companies

Ontario ICI Electricity Pricing Freeze helps Industrial Conservation Initiative (ICI) participants by stabilizing Global Adjustment charges, suspending peak hours curtailment, and reducing COVID-19-related electricity cost volatility to support large employers returning operations to full capacity.

 

Key Points

A two-year policy stabilizing GA costs and pausing peak-hour cuts to aid industrial and commercial recovery.

✅ GA cost share frozen for two years

✅ No peak-hour curtailment obligations

✅ Supports industrial and commercial restart

 

The Ontario government is helping large industrial and commercial companies return to full levels of operation without the fear of electricity costs spiking by providing more stable electricity pricing for two years. Effective immediately, companies that participate in the Industrial Conservation Initiative (ICI) will not be required to reduce their electricity usage during peak hours or shift some load to ultra-low overnight pricing where applicable, as their proportion of Global Adjustment (GA) charges for these companies will be frozen.

"Ontario's industrial and commercial electricity consumers continue to experience unprecedented economic challenges during COVID-19, with electricity relief for households and small businesses introduced to help," said Greg Rickford, Minister of Energy, Northern Development and Mines. "Today's announcement will allow large industrial employers to focus on getting their operations up and running and employees back to work, instead of adjusting operations in response to peak electricity demand hours."

Due to COVID-19, electricity consumption in Ontario has been below average as fall in demand as people stayed home across the province, and the province is forecast to have a reliable supply of electricity, supported by the system operator's staffing contingency plans during the pandemic, to accommodate increased usage. Peak hours generally occur during the summer when the weather is hot and electricity demand from cooling systems is high.

"Today's action will reduce the burden of anticipating and responding to peak hours for more than 1,300 ICI participants with 2,000 primarily industrial facilities in Ontario," said Bill Walker, Associate Minister of Energy. "Now these large employers can focus on getting their operations back up and running at full tilt and explore new energy-efficiency programs to manage costs."

The government previously announced it was providing temporary relief for industrial and commercial electricity consumers that do not participate in the Regulated Price Plan (RPP) by deferring a portion of GA charges for April, May and June 2020 and by extending off-peak rates for many customers, as well as a disconnect moratorium extension for residential electricity users.

 

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COVID-19 Response: Electric Power Industry Closely Coordinating With Federal Partners

ESCC COVID-19 Response coordinates utilities, public power, and cooperatives to protect the energy grid and electricity reliability, aligning with DOE, DHS, CDC, FERC, and NERC on continuity of operations, mutual assistance, and supply chain resilience.

 

Key Points

An industry government effort ensuring reliability, operations continuity and supply chain stability during COVID-19.

✅ Twice weekly ESCC calls align DOE, DHS, HHS, CDC, FERC, NERC priorities.

✅ Focus on control centers, generation, quarantine access, mutual aid.

✅ Resource Guide supports localized decisions and supply chain resilience.

 

The nation’s investor-owned electric companies, public power utilities, and electric cooperatives are working together to protect the energy grid as the U.S. grid addresses COVID-19 challenges and ensure continued access to safe and reliable electricity during the COVID-19 global health crisis.

The electric power industry has been planning for years, including extensive disaster planning across utilities, for an emergency like the COVID-19 pandemic, as well as countless other types of emergencies, and the industry is coordinating closely with government partners through the Electricity Subsector Coordinating Council (ESCC) to ensure that organizations have the resources they need to keep the lights on.

The ESCC is holding high-level coordination calls twice a week with senior leadership from the Departments of Energy, Homeland Security, and Health and Human Services, the Centers for Disease Control and Prevention, the Federal Energy Regulatory Commission, and the North American Electric Reliability Corporation. These calls help ensure that industry and government work together to resolve any challenges that arise during this health emergency and that electricity remains safe for customers.

“Electricity and the energy grid are indispensable to our society, and one of our greatest strengths as an industry is our ability to convene and adapt quickly to changing circumstances and challenging events,” said Edison Electric Institute President Tom Kuhn. “Our industry plans for all types of contingencies, with examples such as local response planning, and strong industry-government coordination and cross-sector collaboration are critical to our planning and response. We appreciate the ongoing leadership and support of our government partners as we all respond to COVID-19 and power through this crisis together.”

The ESCC quickly mobilized and established strategic working groups dedicated to identifying and solving for short-, medium-, and long-term issues facing the industry during the COVID-19 pandemic, with utilities implementing necessary precautions to maintain service across regions.

The five current areas of focus are:

1. Continuity of operations at control centers, including on-site staff lockdowns when needed
2. Continuity of operations at generation facilities
3. Access to, and operations in, restricted or quarantined areas
4. Protocols for mutual assistance
5. Supply chain challenges

“The electric power industry has taken steps to prepare for the evolving coronavirus challenges, while maintaining our commitment to the communities we serve, including customer relief efforts announced by some providers,” said National Rural Electric Cooperative Association CEO Jim Matheson. “We have a strong track record of preparing for many kinds of emergencies that could impact the ability to generate and deliver electricity. While planning for this situation is unique from other business continuity planning, we are taking actions to prepare to operate with a smaller workforce, potential disruptions in the supply chain, and limited support services for an extended period of time.”

The ESCC has developed a COVID-19 Resource Guide linked here and available at electricitysubsector.org. This document was designed to support electric power industry leaders in making informed localized decisions in response to this evolving health crisis. The guide will evolve as additional recommended practices are identified and as more is learned about appropriate mitigation strategies.

“The American Public Power Association (APPA) continues to work with our communityowned public power members and our industry and government partners to gather and share upto-date information, best practices, and guidance to support them in safely maintaining operational integrity,” said APPA CEO Joy Ditto.

 

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