Georgia Power's Plant Bowen tests new technology

By Georgia Power


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A new technology that could significantly reduce the water needed for power plant cooling is being tested, marking the beginning of research and development at the new Water Research Center WRC at Georgia Power's Plant Bowen in Cartersville, Georgia.

Cooling water is essential for most thermal, or steam-driven, electric generation, which is the primary form of producing power in the United States and globally. Although most of the water withdrawn for power generation is returned to the source, the energy industry is focused on finding more efficient ways to manage water resources.

The WRC is the first U.S. research facility of its kind, providing a venue for developing and testing technologies to reduce power plant water withdrawals and consumption and improve the quality of water related to power generation. Operated by the Southern Research Institute, the WRC is being developed by Southern Company and its subsidiary Georgia Power, Southern Research and the Electric Power Research Institute EPRI, which has assembled an R&D collaborative of 13 companies.

"This is the latest demonstration of our commitment at Georgia Power and Southern Company to develop technology solutions for providing safe, clean, reliable and affordable electricity," said Georgia Power Environmental Affairs Vice President Ron Shipman. "The WRC, a first-of-its-kind power generation water research hub at Plant Bowen, is technology leadership at its best."

Evaluation of the new technology – a thermosyphon cooler developed by Johnson Controls – is the first project to become operational at the center. According to Johnson Controls, the technology transfers heat to the environment without evaporative water loss by using an air-cooled refrigerant that pre-cools water before it enters the cooling tower. The thermosyphon cooler reduces the amount of water that must be cooled by evaporation in the cooling tower, thus reducing water consumption. The year-long testing at the WRC will document the technology's water savings potential and energy consumption characteristics.

The Water Research Center is being designed to accommodate development and evaluation of power plant water management technologies in seven areas. These include cooling tower water chemistry and advanced cooling systems process wastewater treatment zero liquid discharge options moisture recovery from power plant processes solids landfill water management carbon technology water issues and water use modeling and monitoring for best management practices.

The technologies being explored at the WRC can be implemented by power companies worldwide to address water issues and also will educate students and community leaders about the importance of water conservation and the technologies being developed to reduce water consumption.

"EPRI is pleased to be working with an industry collaborative that includes so many companies which recognize the importance of this issue of water consumption and the environmental impacts of its use," said Tom Alley, EPRI Vice President of Generation. "Current events of drought and high demands on existing water supplies emphasize the importance of water management."

Georgia Power is the largest subsidiary of Southern Company, one of the nation's largest generators of electricity. The company is an investor-owned, tax-paying utility with rates below the national average. Georgia Power serves 2.4 million customers in all but four of Georgia's 159 counties.

Southern Research is a not-for-profit scientific research organization that conducts advanced engineering research in materials, systems development, environment and energy, and preclinical drug discovery and development.

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Project examines potential for Europe's power grid to increase HVDC Technology

HVDC-WISE Project accelerates HVDC technology integration across the European transmission system, delivering a planning toolkit to boost grid reliability, resilience, and interconnectors for renewables and offshore wind amid climate, cyber, and physical threats.

 

Key Points

EU-funded project delivering tools to integrate HVDC into Europe's grid, improving reliability, resilience, and security.

✅ EU Horizon Europe-backed consortium of 14 partners

✅ Toolkit to assess extreme events and grid operability

✅ Supports interconnectors, offshore wind, and renewables

 

A partnership of 14 leading European energy industry companies, research organizations and universities has launched a new project to identify opportunities to increase integration of HVDC technology into the European transmission system, echoing calls to invest in smarter electricity infrastructure from abroad.

The HVDC-WISE project, in which the University of Strathclyde is the UK’s only academic partner, is supported by the European Union’s Horizon Europe programme.

The project’s goal is to develop a toolkit for grid developers to evaluate the grid’s performance under extreme conditions and to plan systems, leveraging a digital grid approach that supports coordination to realise the full range of potential benefits from deep integration of HVDC technology into the European transmission system.

The project is focused on enhancing electric grid reliability and resilience while navigating the energy transition. Building and maintaining network infrastructure to move power across Europe is an urgent and complex task, and reducing losses with superconducting cables can play a role, particularly with the continuing growth of wind and solar generation. At the same time, threats to the integrity of the power system are on the rise from multiple sources, including climate, cyber, and physical hazards.

 

Mutual support

At a time of increasing worries about energy security and as Europe’s electricity systems decarbonise, connections between them to provide mutual support and routes to market for energy from renewables, a dynamic also highlighted in discussions of the western Canadian electricity grid in North America, become ever more important.

In modern power systems, this means making use of High Voltage Direct Current (HVDC) technology.

The earliest forms of technology have been around since the 1960s, but the impact of increasing reliance on HVDC and its ability to enhance a power system’s operability and resilience are not yet fully understood.

Professor Keith Bell, Scottish Power Professor of Future Power Systems at the University of Strathclyde, said:

As an island, HVDC is the only practical way for us to build connections to other countries’ electricity systems. We’re also making use of it within our system, with one existing and more planned Scotland-England subsea link projects connecting one part of Britain to another.

“These links allow us to maximise our use of wind energy. New links to other countries will also help us when it’s not windy and, together with assets like the 2GW substation now in service, to recover from any major disturbances that might occur.

“The system is always vulnerable to weather and things like lightning strikes or short circuits caused by high winds. As dependency on electricity increases, insights from electricity prediction specialists can inform planning as we enhance the resilience of the system.”

Dr Agusti Egea-Alvarez, Senior Lecturer at Strathclyde, said: “HVDC systems are becoming the backbone of the British and European electric power network, either interconnecting countries, or connecting offshore wind farms.

“The tools, procedures and guides that will be developed during HVDC-WISE will define the security, resilience and reliability standards of the electric network for the upcoming decades in Europe.”

Other project participants include Scottish Hydro Electric Transmission, the Supergrid Institute, the Electric Power Research Institute (EPRI) Europe, Tennet TSO, Universidad Pontificia Comillas, TU Delft, Tractebel Impact and the University of Cyprus.

 

Climate change

Eamonn Lannoye, Managing Director of EPRI Europe, said: “The European electricity grid is remarkably reliable by any standard. But as the climate changes and the grid becomes exposed to more extreme conditions, energy interdependence between regions intensifies and threats from external actors emerge. The new grid needs to be robust to those challenges.”

Juan Carlos Gonzalez, a senior researcher with the SuperGrid Institute which leads the project said: “The HVDC-WISE project is intended to provide planners with the tools and know-how to understand how grid development options perform in the context of changing threats and to ensure reliability.”

HVDC-WISE is supported by the European Union’s Horizon Europe programme under agreement 101075424 and by the UK Research and Innovation Horizon Europe Guarantee scheme.

 

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Electric shock: China power demand drops as coronavirus shutters plants

China Industrial Power Demand 2020 highlights COVID-19 disruption to electricity consumption as factory output stalls; IHS Markit estimates losses equal to Chile's usage, impacting thermal coal, LNG, and Hubei's industrial load.

 

Key Points

An analysis of COVID-19's hit to China's electricity use, cutting industry demand and fuel needs for coal and LNG.

✅ 73 billion kWh loss equals Chile's annual power use

✅ Cuts translate to 30m tonnes coal or 9m tonnes LNG

✅ Hubei peak load 21 percent below plan amid shutdowns

 

China’s industrial power demand in 2020 may decline by as much as 73 billion kilowatt hours (kWh), according to IHS Markit, as the outbreak of the coronavirus has curtailed factory output and prevented some workers from returning to their jobs.

FILE PHOTO: Smoke is seen from a cooling tower of a China Energy ultra-low emission coal-fired power plant during a media tour, in Sanhe, Hebei province, China July 18, 2019. REUTERS/Shivani Singh
The cut represents about 1.5% of industrial power consumption in China. But, as the country is the world’s biggest electricity consumer and analyses of China's electricity appetite routinely underscore its scale, the loss is equal to the power used in the whole of Chile and it illustrates the scope of the disruption caused by the outbreak.

The reduction is the energy equivalent of about 30 million tonnes of thermal coal, at a time when China aims to reduce coal power production, or about 9 million tonnes of liquefied natural gas (LNG), IHS said. The coal figure is more than China’s average monthly imports last year while the LNG figure is a little more than one month of imports, based on customs data.

China has tried to curtail the spread of the coronavirus that has killed more than 1,400 and infected over 60,000 by extending the Lunar New Year holiday for an extra week and encouraging people to work from home, measures that contributed to a global dip in electricity demand as well.

Last year, industrial users consumed 4.85 trillion kWh electricity, accounting for 67% of the country’s total, even as India's electricity demand showed sharp declines in the region.

Xizhou Zhou, the global head of power and Renewables at IHS Markit, said that in a severe case where the epidemic goes on past March, China’s economic growth will be only 4.2% during 2020, down from an initial forecast of 5.8%, while power consumption will climb by only 3.1%, down from 4.1% initially, even as power cuts and blackouts raise concerns.

“The main uncertainty is still how fast the virus will be brought under control,” said Zhou, adding that the impact on the power sector will be relatively modest from a full-year picture in 2020, even though China's electric power woes are already clouding solar markets.

In Hubei province, the epicenter of the virus outbreak, the peak power load at the end of January was 21% less than planned, mirroring how Japan's power demand was hit during the outbreak, data from Wood Mackenzie showed.

Industrial operating rates point to a firm reduction in power consumption in China.

Utilization rates at plastic processors are between 30% and 60% and the low levels are expected to last for another two week, according to ICIS China.

Weaving machines at textile plants are operating at below 10% of capacity, the lowest in five years, ICIS data showed. China is the world’s biggest textile and garment exporter.

 

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How Alberta’s lithium-laced oil fields can fuel the electric vehicle revolution

Alberta Lithium Brine can power EV batteries via direct lithium extraction, leveraging oilfield infrastructure and critical minerals policy to build a low-carbon supply chain with clean energy, lower emissions, and domestic manufacturing advantages.

 

Key Points

Alberta lithium brine is subsurface saline water rich in lithium, extracted via DLE to supply EV batteries.

✅ Uses direct lithium extraction from oilfield brines

✅ Leverages Alberta infrastructure and skilled workforce

✅ Supports EV battery supply chain with lower emissions

 

After a most difficult several months, Canadians are cautiously emerging from their COVID-19 isolation and confronting a struggling economy.
There’s a growing consensus that we need to build back better from COVID-19, and to position for the U.S. auto sector’s pivot to electric vehicles as supply chains evolve. Instead of shoring up the old economy as we did following the 2008 financial crisis, we need to make strategic investments today that will prepare Canada for tomorrow’s economy.

Tomorrow’s energy system will look very different from today’s — and that tomorrow is coming quickly. The assets of today’s energy economy can help build and launch the new industries required for a low-carbon future. And few opportunities are more intriguing than the growing lithium market.

The world needs lithium – and Alberta has plenty

It’s estimated that three billion tonnes of metals will be required to generate clean energy by 2050. One of those key metals – lithium, a light, highly conductive metal – is critical to the construction of battery electric vehicles (BEV). As global automobile manufacturers design hundreds of new BEVs, demand for lithium is expected to triple in the next five years alone, a trend sharpened by pandemic-related supply risks for automakers.

Most lithium today originates from either hard rock or salt flats in Australia and South America. Alberta’s oil fields hold abundant deposits of lithium in subsurface brine, but so far it’s been overlooked as industrial waste. With new processing technologies and growing concerns about the security of global supplies, this is set to change. In January, Canada and the U.S. finalized a Joint Action Plan on Critical Minerals to ensure supply security for critical minerals such as lithium and to promote supply chains closer to home, aligning with U.S. efforts to secure EV metals among allies worldwide.

This presents a major opportunity for Canada and Alberta. Lithium brine will be produced much like the oil that came before it. This lithium originates from many of the same reservoirs responsible for driving both Alberta’s economy and the broader transportation fuel sector for decades. The province now has extensive geological data and abundant infrastructure, including roads, power lines, rail and well sites. Most importantly, Alberta has a highly trained workforce. With very little retooling, the province could deliver significant volumes of newly strategic lithium.

Specialized technologies known as direct lithium extraction, or DLE, are being developed to unlock lithium-brine resources like those in Canada. In Alberta, E3 Metals* has formed a development partnership with U.S. lithium heavyweight Livent Corporation to advance and pilot its DLE technology. Prairie Lithium and LiEP Energy formed a joint venture to pilot lithium extraction in Saskatchewan. And Vancouver’s Standard Lithium is already piloting its own DLE process in southern Arkansas, where the geology is very similar to Alberta and Saskatchewan.

Heavy on quality, light on emissions

All lithium produced today has a carbon footprint, most of which can be tied back to energy-intensive processing. The purity of lithium is essential to battery safety and performance, but this comes at a cost when lithium is mined with trucks and shovels and then refined in coal-heavy China.

As automakers look to source more sustainable raw materials, battery recycling will complement responsible extraction, and Alberta’s experience with green technologies such as renewable electricity and carbon capture and storage can make it one of the world’s largest suppliers of zero-carbon lithium.

Beyond raw materials

The rewards would be considerable. E3 Metals’ Alberta project alone could generate annual revenues of US$1.8 billion by 2030, based on projected production and price forecasts. This would create thousands of direct jobs, as initiatives like a lithium-battery workforce initiative expand training, and many more indirectly.

To truly grow this industry, however, Canada needs to move beyond its comfort zone. Rather than produce lithium as yet another raw-commodity export, Canadians should be manufacturing end products, such as batteries, for the electrified economy, with recent EV assembly deals underscoring Canada’s momentum. With nickel and cobalt refining, graphite resources and abundant petrochemical infrastructure already in place, Canada must aim for a larger piece of the supply chain.

By 2030, the global battery market is expected to be worth $116 billion annually. The timing is right to invest in a strategic commodity and grow our manufacturing sector. This is why the Alberta-based Energy Futures Lab has called lithium one of the ‘Five big ideas for Alberta’s economic recovery.’  The assets of today’s energy economy can be used to help build and launch new resource industries like lithium, required for the low-carbon energy system of the future.

Industry needs support

To do this, however, governments will have to step up the way they did a generation ago. In 1975, the Alberta government kick-started oil-sands development by funding the Alberta Oil Sands Technology and Research Authority. AOSTRA developed a technology called SAGD (steam-assisted gravity drainage) that now accounts for 80% of Alberta’s in situ oil-sands production.

Canada’s lithium industry needs similar support. Despite the compelling long-term economics of lithium, some industry investors need help to balance the risks of pioneering such a new industry in Canada. The U.S. government has recognized a similar need, with the Department of Energy’s recent US$30 million earmarked for innovation in critical minerals processing and the California Energy Commission’s recent grants of US$7.8 million for geothermal-related lithium extraction.

To accelerate lithium development in Canada, this kind of leadership is needed. Government-assisted financing could help early-stage lithium-extraction technologies kick-start a whole new industry.

Aspiring lithium producers are also looking for government’s help to repurpose inactive oil and gas wells. The federal government has earmarked $1 billion for cleaning up inactive Alberta oil wells. Allocating a small percentage of that total for repurposing wells could help transform environmental liabilities into valuable clean-energy assets.

The North American lithium-battery supply chain will soon be looking for local sources of supply, and there is room for Canada-U.S. collaboration as companies turn to electric cars, strengthening regional resilience.
 

 

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Seven small UK energy suppliers must pay renewables fees or risk losing licence

Ofgem Renewables Obligations drive supplier payments for renewables fees, feed-in tariffs, and renewable generation, with non-payment risking supply licences amid the price cap and volatile wholesale prices across the UK energy market.

 

Key Points

Mandatory payments by suppliers funding renewables via feed-in tariffs; non-payment can trigger supply licence revoking.

✅ Covers Renewables Obligation and Feed-in Tariff scheme compliance.

✅ Non-payment can lead to Ofgem action and licence loss.

✅ Affected by price cap and wholesale price volatility.

 

Seven small British energy suppliers owe a total of 34 million pounds ($43.74 million) in renewables fees, amid a renewables backlog that has stalled projects, and could face losing their supply licences if they cannot pay, energy regulator Ofgem reports.

Under Britain’s energy market rules, suppliers of energy must meet so-called renewables obligations and feed-in tariffs, including households' ability to sell solar power back to energy firms, which are imposed on them by the government to help fund renewable power generation.

Several small energy companies have gone bust over the past two years, a trend echoed by findings from a global utility study on renewable priorities, as they struggled to pay the renewables fees and as their profits were affected by a price cap on the most commonly used tariffs and fluctuating wholesale prices, even as a 10 GW contract brings new renewable capacity onto the UK grid.

Ofgem has called on the companies to make necessary payments by Oct. 31, as moves to offer community-generated power to all UK customers progress.

“If they do not pay Ofgem could start the process of revoking their licences to supply energy,” it said in a statement, as offshore wind power continues to scale nationwide.

The seven suppliers are, amid debates over clean energy impacts, Co-Operative Energy Limited; Flow Energy Limited; MA Energy Limited; Nabuh Energy Limited; Robin Hood Energy Limited; Symbio Energy Limited and Tonik Energy Limited. ($1 = 0.7773 pounds)

 

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Tesla CEO Elon Musk slams Texas energy agency as unreliable: "not earning that R"

ERCOT Texas Power Grid Crisis disrupts millions amid a winter storm, with rolling blackouts, power outages, and energy demand; Elon Musk criticizes ERCOT as Tesla owners use Camp Mode while wind turbines face icing

 

Key Points

A Texas blackout during a winter storm, exposing ERCOT failures, rolling blackouts, and urgent grid resilience measures.

✅ Millions without power amid record cold and energy demand

✅ Elon Musk criticizes ERCOT over grid reliability failures

✅ Tesla Camp Mode aids warmth during extended outages

 

Tesla CEO Elon Musk on Wednesday slammed the Texas agency responsible for a statewide blackout amid a U.S. grid with frequent outages that has left millions of people to fend for themselves in a freezing cold winter storm.

Musk tweeted that Texas’ power grid manager, the Electricity Reliability Council of Texas (ERCOT), is not earning the “R” in the acronym, highlighting broader grid vulnerabilities that critics have noted.

Musk moved to Texas from California in December and is building a new Tesla factory in Austin. His critique of the state’s electrical grid operator came after multiple Tesla owners in the state said they had slept in their vehicles to keep warm amid the lingering power outage.

In 2019, Tesla released a vehicle with a “Camp Mode,” which enables owners to use the vehicle’s features – like lights and climate control – without significantly depleting the battery.

“We had the power go out for 6 hours last night. Our house does not have gas, and we ran out of firewood... what are we going to do,” one Reddit user wrote on “r/TeslaMotors.”

“So my wife my dog and my newborn daughter slept in the garage in our Model3 all nice and cozy. If I didn't have this car, it would have been a very rough night.”

More than two dozen people have died in the extreme weather this week, some while struggling to find warmth inside their homes. In the Houston area, one family succumbed to carbon monoxide from car exhaust in their garage. Another perished as they used a fireplace to keep warm.

Utilities from Minnesota to Texas and Mississippi have implemented rolling blackouts to ease the burden on power grids straining to meet extreme demand for heat and electricity, as longer, more frequent outages hit systems nationwide.

More than 3 million customers remained without power in Texas, Louisiana and Mississippi, more than 200,000 more in four Appalachian states, and nearly that many in the Pacific Northwest, according to poweroutage.us, which tracks utility outage reports, and advocates warn that millions could face summer shut-offs without protections.

ERCOT said early Wednesday that electricity had been restored to 600,000 homes and businesses by Tuesday night, though nearly 3 million homes and businesses remained without power, as California turns to batteries to help balance demand. Officials did not know when power would be restored.

ERCOT President Bill Magness said he hoped many customers would see at least partial service restored soon but could not say definitively when that would be.

Magness has defended ERCOT’s decision, saying it prevented an “even more catastrophic than the terrible events we've seen this week."

Utility crews raced Wednesday to restore power to nearly 3.4 million customers around the U.S. who were still without electricity in the aftermath of a deadly winter storm, even as officials urge residents to prepare for summer blackouts that could tax systems further, and another blast of ice and snow threatened to sow more chaos.

The latest storm front was expected to bring more hardship to states that are unaccustomed to such frigid weather — parts of Texas, Arkansas and the Lower Mississippi Valley — before moving into the Northeast on Thursday.

"There's really no letup to some of the misery people are feeling across that area," said Bob Oravec, lead forecaster with the National Weather Service, referring to Texas.

Sweden, known for its brutally cold climate, has offered some advice to Texans unaccustomed to such freezing temperatures, as Canadian grids are increasingly exposed to harsh weather that strains reliability. Stefan Skarp of the Swedish power company told Bloomberg on Tuesday: “The problem with sub-zero temperatures and humid air is that ice will form on the wind turbines.”

“When ice freezes on to the wings, the aerodynamic changes for the worse so that wings catch less and less wind until they don't catch any wind at all,” he said.

 

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How Canada can capitalize on U.S. auto sector's abrupt pivot to electric vehicles

Canadian EV Manufacturing is accelerating with GM, Ford, and Project Arrow, integrating cross-border supply chains, battery production, rare-earths like lithium and cobalt, autonomous tech, and home charging to drive clean mobility and decarbonization.

 

Key Points

Canadian EV manufacturing spans electric and autonomous vehicles, domestic batteries, and integrated US-Canada trade.

✅ GM and Ford retool plants for EVs and autonomous production

✅ Project Arrow showcases Canadian zero-emission supply capabilities

✅ Lithium, cobalt, and battery hubs target cross-border resilience

 

The storied North American automotive industry, the ultimate showcase of Canada’s high-tensile trade ties with the United States and emerging Canada-U.S. collaboration on EVs momentum, is about to navigate a dramatic hairpin turn.

But as the Big Three veer into the all-electric, autonomous era, some Canadians want to seize the moment and take the wheel.

“There’s a long shadow between the promise and the execution, but all the pieces are there,” says Flavio Volpe, president of the Automotive Parts Manufacturers’ Association.

“We went from a marriage on the rocks to one that both partners are committed to. It could be the best second chapter ever.”

Volpe is referring specifically to GM, which announced late last month an ambitious plan to convert its entire portfolio of vehicles to an all-electric platform by 2035.

But that decision is just part of a cascading transformation across the industry, marking an EV inflection point with existential ramifications for one of the most tightly integrated cross-border manufacturing and supply-chain relationships in the world.

China is already working hard to become the “source of a new way” to power vehicles, President Joe Biden warned last week.

“We just have to step up.”

Canada has both the resources and expertise to do the same, says Volpe, whose ambitious Project Arrow concept — a homegrown zero-emissions vehicle named for the 1950s-era Avro interceptor jet — is designed to showcase exactly that, as recent EV assembly deals in Canada underscore.

“We’re going to prove to the market, we’re going to prove to the (manufacturers) around the planet, that everything that goes into your zero-emission vehicle can be made or sourced here in Canada,” he says.

“If somebody wants to bring what we did over the line and make 100,000 of them a year, I’ll hand it to them.”

GM earned the ire of Canadian auto workers in 2018 by announcing the closure of its assembly plant in Oshawa, Ont. It later resurrected the facility with a $170-million investment to retool it for autonomous vehicles.

“It was, ‘You closed Oshawa, how dare you?’ And I was one of the ‘How dare you’ people,” Volpe says.

“Well, now that they’ve reopened Oshawa, you sit there and you open your eyes to the commitment that General Motors made.”

Ford, too, has entered the fray, promising $1.8 billion to retool its sprawling landmark facility in Oakville, Ont., to build EVs.

It’s a leap of faith of sorts, considering what market experts say is ongoing consumer doubt about EVs and EV supply shortages that drive wait times.

“Range anxiety” — the persistent fear of a depleted battery at the side of the road — remains a major concern, even though it’s less of a problem than most people think.

Consulting firm Deloitte Canada, which has been tracking automotive consumer trends for more than a decade, found three-quarters of future EV buyers it surveyed planned to charge their vehicles at home overnight.

“The difference between what is a perceived issue in a consumer’s mind and what is an actual issue is actually quite negligible,” Ryan Robinson, Deloitte’s automotive research leader, says in an interview.

“It’s still an issue, full stop, and that’s something that the industry is going to have to contend with.”

So, too, is price, especially with the end of the COVID-19 pandemic still a long way off. Deloitte’s latest survey, released last month, found 45 per cent of future buyers in Canada hope to spend less than $35,000 — a tall order when most base electric-vehicle models hover between $40,000 and $45,000.

“You put all of that together and there’s still, despite the electric-car revolution hype, some major challenges that a lot of stakeholders that touch the automotive industry face,” Robinson says.

“It’s not just government, it’s not just automakers, but there are a variety of stakeholders that have a role to play in making sure that Canadians are ready to make the transition over to electric mobility.”

With protectionism no longer a dirty word in the United States and Biden promising to prioritize American workers and suppliers, the Canadian government’s job remains the same as it ever was: making sure the U.S. understands Canada’s mission-critical role in its own economic priorities.

“We’re both going to be better off on both sides of the border, as we have been in the past, if we orient ourselves toward this global competition as one force,” says Gerald Butts, vice-chairman of the political-risk consultancy Eurasia Group and a former principal secretary to Prime Minister Justin Trudeau.

“It served us extraordinarily well in the past … and I have no reason to believe it won’t serve us well in the future.”

Last month, GM announced a billion-dollar plan to build its new all-electric BrightDrop EV600 van in Ingersoll, Ont., at Canada’s first large-scale EV manufacturing plant for delivery vehicles.

That investment, Volpe says, assumes Canada will take the steps necessary to help build a homegrown battery industry — with projects such as a new Niagara-region battery plant pointing the way — drawing on the country’s rare-earth resources like lithium and cobalt that are waiting to be extracted in northern Ontario, Quebec and elsewhere.

Given that the EV industry is still in his infancy, the free market alone won’t be enough to ensure those resources can be extracted and developed, he says.

“General Motors made a billion-dollar bet on Canada because it’s going to assume that the Canadian government — this one or the next one — is going to commit” to building that business.

Such an investment would pay dividends well beyond the auto sector, considering the federal Liberal government’s commitment to lowering greenhouse gas-emissions, including a 2035 EV mandate, and meeting targets set out in the Paris climate accord.

“If you make investments in renewable energy and utility storage using battery technology, you can build an industry at scale that the auto industry can borrow,” Volpe says.

Major manufacturing, retail and office facilities would be able to use that technology to help “shave the peak” off Canada’s GHG emissions and achieve those targets, all the while paving the way for a self-sufficient electric-vehicle industry.

“You’d be investing in the exact same technology you’d use in a car.”

There’s one problem, says Robinson: the lithium-ion batteries on roads right now might not be where the industry ultimately lands.

“We’re not done with with battery technology,” Robinson says. “What you don’t want to do is invest in a technology that is that is rapidly evolving, and could potentially become obsolete going forward.”

Fuel cells — energy-efficient, hydrogen-powered units that work like batteries, but without the need for constant recharging — continue to be part of the conversation, he adds.

“The amount of investment is huge, and you want to be sure that you’re making the right decision, so you don’t find yourself behind the curve just as all that capacity is coming online.”

 

 

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