GE calls for trade deal in environmental goods

By Reuters


Protective Relay Training - Basic

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 12 hours Instructor-led
  • Group Training Available
Regular Price:
$699
Coupon Price:
$599
Reserve Your Seat Today
A deal freeing up trade in environmental goods and services is urgently needed to help global efforts to tackle climate change, General Electric Co said.

GE's senior counsel for intellectual property and trade, Thaddeus Burns, said the deal should be negotiated separately from the World Trade Organization's Doha round of talks to open up world trade. The Doha talks are in their eighth year with no sign of a breakthrough.

The call by the world's biggest maker of electric turbines and jet engines focused attention on the difficulties of reconciling environment and energy policy with trade rules.

"We believe that some kind of multilateral agreement... could be something that would be very useful for spurring the diffusion of green technology, both in the form of goods and services," Burns told an energy conference at the WTO.

One model could be the agreement on information technology, negotiated by a group of WTO members to eliminate duties on a range of high-tech products to foster technological development.

WTO Director-General Pascal Lamy says international agreements to curb greenhouse emissions, say at December's Copenhagen climate summit, need not conflict with trade rules.

But trade experts say there is still plenty of scope for trade disputes arising from the application of emission curbs and many legal grey areas would need to be clarified.

Burns cited the example of wind turbines, in which GE — a multinational manufacturing and selling around the globe — is encountering high tariffs.

Five countries — Denmark, Germany, India, Japan and Spain — account for 93 percent of world production of wind turbines, helped by a favorable regulatory regime in the European Union.

The biggest producers are Denmark's Vestas, GE, Spain's Gamesa, Germany's Enercon and Siemens, and India's Suzion.

But the product, a key source of renewable energy, is subject to an average tariff of 7.5 percent around the world, ranging from 14 percent in Brazil, 8 percent in China to 2.7 percent in the EU and 1.3 percent in the United States.

An agreement that cuts and rationalizes these tariffs — imposed on global trade in wind turbines and parts of nearly $6.6 billion in 2008 — would promote green technology, he said.

Green technology producers also face non-tariff barriers — regulatory red-tape and standards — that block their sales.

Because much energy infrastructure is bought by governments, state procurement policies such as "Buy America" in the United States and similar measures in China and Canada are disrupting trade in green goods.

Burns cited the example of GE's hydro technology, produced in Canada, a center for advanced water energy. U.S. "Buy America" policies mean this cannot be sold in the United States.

Similar barriers are faced by Brazil, the world's biggest exporter of ethanol, said a senior Brazilian diplomat.

Flavio Damico, Brazil's deputy ambassador to the WTO, told the conference ethanol faced tariffs of 42.9 percent and 46.0 percent it the European Union and United States respectively, against zero on oil.

Measures to promote sustainable development could also turn out to be discriminatory, targeting other countries' production.

"If people are serious about emissions, why tax clean, renewable fuels while dirty, non-renewable and price-volatile oil is admitted duty-free?" he asked.

The result was that ethanol was treated like an agricultural product, with only 10 percent of world production — which hit 79 billion liters in 2008 — traded globally.

Related News

Utility giant Electricite de France acquired 50pc stake in Irish offshore wind farm

Codling Bank Offshore Wind Project will deliver a 1.1 GW offshore wind farm off the Wicklow coast, as EDF Renewables and Fred Olsen Renewables invest billions to support Ireland's CAP 2030 and cut carbon emissions.

 

Key Points

A 1.1 GW offshore wind farm off Co Wicklow, led by EDF and Fred Olsen, advancing Ireland's CAP 2030 targets.

✅ Up to 1.1 GW capacity; hundreds of turbines off Co Wicklow

✅ EDF Renewables partners with Fred Olsen Renewables

✅ Investment well over €2bn, supporting 70% electricity by 2030

 

It’s been previously estimated that the entire Codling Bank project, which will eventually see hundreds of wind turbines, such as a huge offshore wind turbine now coming to market, erected about 13km off the Co Wicklow coast, could be worth as much as €100m. The site is set to generate up to 1.1 gigawatts of electricity when it’s eventually operational.

It’s likely to cost well over €2bn to develop, and with new pipelines abroad where Long Island offshore turbine proposals are advancing, scale economies are increasingly relevant.

The other half of the project is owned by Norway’s Fred Olsen Renewables, with tens of millions of euro already reportedly spent on surveys and other works associated with the scheme. Initial development work started in 2003.

Mr Barrett will now continue to focus on his non-Irish renewable projects, at a time when World Bank wind power support is accelerating in developing countries, said Hazel Shore, the company that sold the stake. It added that Johnny Ronan and Conor Ronan, the developer’s brother, will retain an equity interest in the Codling project.

“The Hazel Shore shareholders remain committed to continuing their renewable and forestry businesses,” noted the firm, whose directors include Paddy Teahon, a former secretary of the Department of the Taoiseach and chairman of the National Offshore Wind Association of Ireland.

The French group’s EDF Renewables subsidiary will now partner with the Norwegian firm to develop and build the Codling Bank project, in a sector widely projected to become a $1 trillion business over the coming decades.

EDF pointed out that the acquisition of the Codling Bank stake comes after the government committed to reducing carbon emissions. A Climate Action Plan launched last year will see renewable projects generating 70pc of Ireland’s electricity by 2030, with more than a third of Irish electricity to be green within four years according to recent analysis. Offshore wind is expected to deliver at least 3.5GW of power in support of the objective.

Bruno Bensasson, EDF Group senior executive vice-president of renewable energies and the CEO of EDF Renewables said the French group is “committed to contributing to the Irish government’s renewables goals”.

“This important project clearly strengthens our strong ambition to be a leading global player in the offshore wind industry,” he added. “This is consistent with the CAP 2030 strategy that aims to double EDF’s renewable energy generation by 2030 and increase it to 50GW net.”

Matthieu Hue, the CEO of EDF Renewables UK and Ireland said the firm already has an office in Dublin and is looking for further renewable projects, as New York's biggest offshore wind farm moves ahead, underscoring momentum.

Last November, the ESB teamed up with EDF in Scotland, reflecting how UK offshore wind is powering up, with the Irish utility buying a 50pc stake in the Neart na Gaoithe offshore wind project. The massive wind farm is expected to generate up to 450MW of electricity and will cost about €2.1bn to develop.

EDF said work on that project is “well under way”.

 

Related News

View more

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.

 

Related News

View more

Electricity Grids Can Handle Electric Vehicles Easily - They Just Need Proper Management

EV Grid Capacity Management shows how smart charging, load balancing, and off-peak pricing align with utility demand response, DC fast charging networks, and renewable integration to keep national electricity infrastructure reliable as EV adoption scales

 

Key Points

EV Grid Capacity Management schedules charging and balances load to keep EV demand within utility capacity.

✅ Off-peak pricing and time-of-use tariffs shift charging demand.

✅ Smart chargers enable demand response and local load balancing.

✅ Gradual EV adoption allows utilities to plan upgrades efficiently.

 

One of the most frequent concerns you will see from electric vehicle haters is that the electricity grid can’t possibly cope with all cars becoming EVs, or that EVs will crash the grid entirely. However, they haven’t done the math properly. The grids in most developed nations will be just fine, so long as the demand is properly management. Here’s how.

The biggest mistake the social media keyboard warriors make is the very strange assumption that all cars could be charging at once. In the UK, there are currently 32,697,408 cars according to the UK Department of Transport. The UK national grid had a capacity of 75.8GW in 2020. If all the cars in the UK were EVs and charging at the same time at 7kW (the typical home charger rate), they would need 229GW – three times the UK grid capacity. If they were all charging at 50kW (a common public DC charger rate), they would need 1.6TW – 21.5 times the UK grid capacity. That sounds unworkable, and this is usually the kind of thinking behind those who claim the UK grid can't cope with EVs.

What they don’t seem to realize is that the chances of every single car charging all at once are infinitesimally low. Their arguments seem to assume that nobody ever drives their car, and just charges it all the time. If you look at averages, the absurdity of this position becomes particularly clear. The distance each UK car travels per year has been slowly dropping, and was 7,400 miles on average in 2019, again according to the UK Department of Transport. An EV will do somewhere between 2.5 and 4.5 miles per kWh on average, so let’s go in the middle and say 3.5 miles. In other words, each car will consume an average of 2,114kWh per year. Multiply that by the number of cars, and you get 69.1TWh. But the UK national grid produced 323TWh of power in 2019, so that is only 21.4% of the energy it produced for the year. Before you argue that’s still a problem, the UK grid produced 402TWh in 2005, which is more than the 2019 figure plus charging all the EVs in the UK put together. The capacity is there, and energy storage can help manage EV-driven peaks as well.

Let’s do the same calculation for the USA, where an EV boom is about to begin and planning matters. In 2020, there were 286.9 million cars registered in America. In 2020, while the US grid had 1,117.5TW of utility electricity capacity and 27.7GW of solar, according to the US Energy Information Administration. If all the cars were EVs charging at 7kW, they would need 2,008.3TW – nearly twice the grid capacity. If they charged at 50kW, they would need 14,345TW – 12.8 times the capacity.

However, in 2020, the US grid generated 4,007TWh of electricity. Americans drive further on average than Brits – 13,500 miles per year, according to the US Department of Transport’s Federal Highway Administration. That means an American car, if it were an EV, would need 3,857kWh per year, assuming the average efficiency figures above. If all US cars were EVs, they would need a total of 1,106.6TWh, which is 27.6% of what the American grid produced in 2020. US electricity consumption hasn’t shrunk in the same way since 2005 as it has in the UK, but it is clearly not unfeasible for all American cars to be EVs. The US grid could cope too, even as state power grids face challenges during the transition.

After all, the transition to electric isn’t going to happen overnight. The sales of EVs are growing fast, with for example more plug-ins sold in the UK in 2021 so far than the whole of the previous decade (2010-19) put together. Battery-electric vehicles are closing in on 10% of the market in the UK, and they were already 77.5% of new cars sold in Norway in September 2021. But that is new cars, leaving the vast majority of cars on the road fossil fuel powered. A gradual introduction is essential, too, because an overnight switchover would require a massive ramp up in charge point installation, particularly devices for people who don’t have the luxury of home charging. This will require considerable investment, but could be served by lots of chargers on street lamps, which allegedly only cost £1,000 ($1,300) each to install, usually with no need for extra wiring.

This would be a perfectly viable way to provide charging for most people. For example, as I write this article, my own EV is attached to a lamppost down the street from my house. It is receiving 5.5kW costing 24p (32 cents) per kWh through SimpleSocket, a service run by Ubitricity (now owned by Shell) and installed by my local London council, Barnet. I plugged in at 11am and by 7.30pm, my car (which was on about 28% when I started) will have around 275 miles of range – enough for a couple more weeks. It will have cost me around £12 ($16) – way less than a tank of fossil fuel. It was a super-easy process involving the scanning of a QR code and entering of a credit card, very similar to many parking systems nowadays. If most lampposts had one of these charging plugs, not having off-street parking would be no problem at all for owning an EV.

With most EVs having a range of at least 200 miles these days, and the average mileage per day being 20 miles in the UK (the 7,400-mile annual figure divided by 365 days) or 37 miles in the USA, EVs won’t need charging more than once a week or even every week or two. On average, therefore, the grids in most developed nations will be fine. The important consideration is to balance the load, because if too many EVs are charging at once, there could be a problem, and some regions like California are looking to EVs for grid stability as part of the solution. This will be a matter of incentivizing charging during off-peak times such as at night, or making peak charging more expensive. It might also be necessary to have the option to reduce charging power rates locally, while providing the ability to prioritize where necessary – such as emergency services workers. But the problem is one of logistics, not impossibility.

There will be grids around the world that are not in such a good place for an EV revolution, at least not yet, and some critics argue that policies like Canada's 2035 EV mandate are unrealistic. But to argue that widespread EV adoption will be an insurmountable catastrophe for electricity supply in developed nations is just plain wrong. So long as the supply is managed correctly to make use of spare capacity when it’s available as much as possible, the grids will cope just fine.

 

Related News

View more

Ontario Breaks Ground on First Small Modular Nuclear Reactor

Ontario SMR BWRX-300 leads Canada in next-gen nuclear energy at Darlington, with GE Vernova and Hitachi, delivering clean, reliable power via modular design, passive safety, scalability, and lower costs for grid integration.

 

Key Points

Ontario SMR BWRX-300 is a 300 MW modular boiling water reactor at Darlington with passive safety and clean power.

✅ 300 MW BWR supplies power for about 300,000 homes

✅ Passive safety enables safe shutdown without external power

✅ Modular design reduces costs and speeds grid integration

 

Ontario has initiated the construction of Canada's first small modular nuclear reactor (SMR), supported by OPG's SMR commitment to deployment, marking a significant milestone in the province's energy strategy. This development positions Ontario at the forefront of next-generation nuclear technology within the G7 nations.

The project, known as the Darlington New Nuclear Project, is being led by Ontario Power Generation (OPG) in collaboration with GE Vernova and Hitachi Nuclear Energy, and through its OPG-TVA partnership on new nuclear technology development. The chosen design is the BWRX-300, a 300-megawatt boiling water reactor that is approximately one-tenth the size and complexity of traditional nuclear reactors. The first unit is expected to be operational by 2029, with plans for additional units to follow.

Each BWRX-300 reactor is projected to supply electricity to about 300,000 homes, contributing to Ontario's efforts, which include the decision to refurbish Pickering B for additional baseload capacity, to meet the anticipated 75% increase in electricity demand by 2050. The compact design of the SMR allows for easier integration into existing infrastructure, reducing the need for extensive new transmission lines.

The economic impact of the project is substantial. The construction of four such reactors is expected to create up to 18,000 jobs and contribute approximately $38.5 billion CAD to the Canadian economy, reflecting the economic benefits of nuclear projects over 65 years. The modular nature of SMRs also allows for scalability, with each additional unit potentially reducing costs through economies of scale.

Safety is a paramount consideration in the design of the BWRX-300. The reactor employs passive safety features, meaning it can safely shut down without the need for external power or operator intervention. This design enhances the reactor's resilience to potential emergencies, aligning with stringent regulatory standards.

Ontario's commitment to nuclear energy is further demonstrated by its plans for four SMRs at the Darlington site. This initiative reflects a broader strategy to diversify the province's energy mix, incorporating clean and reliable power sources to complement renewable energy efforts.

While the development of SMRs in Ontario is a significant step forward, it also aligns with the Canadian nuclear initiative positioning Canada as a leader in the global nuclear energy landscape. The successful implementation of the BWRX-300 could serve as a model for other nations exploring advanced nuclear technologies.

Ontario's groundbreaking work on small modular nuclear reactors represents a forward-thinking approach to energy generation. By embracing innovative technologies, the province is not only addressing future energy demands but also, through the Pickering NGS life extension, contributing to the global transition towards sustainable and secure energy solutions.

 

Related News

View more

California Regulators Face Calls for Action as Electricity Bills Soar

California Electricity Rate Hikes strain households as CPUC weighs fixed charges, utility profit caps, and stricter oversight. Wildfire mitigation, transmission upgrades, and aging grid costs push bills higher amid renewable integration and consumer protection debates.

 

Key Points

California power rates are rising from wildfire mitigation, transmission costs, and grid upgrades under CPUC review.

✅ CPUC mulls fixed charges to stabilize bills and rate design.

✅ Advocates push profit caps; utilities cite investment needs.

✅ Stronger oversight sought to curb waste and boost transparency.

 

California residents and consumer groups are demanding relief as their electricity bills continue to climb, putting increasing pressure on state regulators to intervene.  A recent op-ed in the San Francisco Chronicle highlights the growing frustration, emphasizing that California already has some of the highest electricity rates in the country, as coverage on why prices are soaring underscores, and these costs are only getting more burdensome.


Factors Driving High Bills

The rising electricity bills are attributed to several factors:

  • Wildfire Mitigation and Liability: Utility companies are investing heavily in wildfire prevention measures, such as vegetation management and infrastructure hardening. The costs of these initiatives, along with the increasing financial liabilities associated with wildfire risk, are being passed on to consumers.
  • Transmission Costs: California's vast geography and move towards renewable energy sources necessitate significant investments in transmission lines to deliver electricity from remote locations. These infrastructure costs also contribute to higher bills.
  • Aging Infrastructure: California's electricity grid is aging and requires upgrades and maintenance, and the expenses associated with these efforts are reflected in consumer rates.


Proposed Solutions and Debates

Consumer advocates and some lawmakers are calling for various actions to address the issue, including a potential revamp of electricity rates to clean the grid:

  • Fixed Charge Proposal: The California Public Utilities Commission (CPUC) is considering a proposal to introduce an income-based fixed charge on electricity bills. This change aims to make rates more predictable and encourage investment in renewable energy sources. However, opponents argue that it could disproportionately impact low-income households and discourage conservation.
  • Utility Profit Caps: Some advocate for capping utility companies' profits. They believe excessive profits should be returned to customers in the form of lower rates. However, utility companies counter that they need a certain level of profit to invest in infrastructure and maintain a reliable grid.
  • Increased Oversight: Consumer groups are calling for stricter oversight of utility company spending, and legislators are preparing to crack down on utility spending through upcoming votes as well. They demand transparency and want to ensure that funds collected from customers are being used for necessary investments and not for lobbying or excessive executive compensation.

 

Comparisons and National Implications

Similar concerns about rising utility bills are emerging in other parts of the country as more states transition to renewable energy and invest in infrastructure upgrades.

A report by the Energy Information Administration (EIA) shows that average residential electricity rates across the country have been on the rise for the past decade. While California currently ranks amongst the highest, major changes to electric bills are being debated, and other states are following suit, demonstrating the nationwide challenge of balancing affordability with necessary investments.

 

Uncertain Future

The California Public Utilities Commission is reviewing the fixed charge proposal and is expected to make a decision later this year, with income-based flat-fee utility bills moving closer in the process. The outcome of this decision and potential additional regulatory changes will have significant ramifications for California residents, and some lawmakers plan to overturn income-based charges if adopted, which could set a precedent for how other states handle the rising costs associated with the energy transition.

 

Related News

View more

Electric vehicle sales triple in Australia despite lack of government support

Australian Electric Vehicle Sales tripled in 2019 amid expanding charging infrastructure and more models, but market share remains low, constrained by limited government policy, weak incentives, and absent emissions standards despite growing ultra-fast chargers.

 

Key Points

EV units sold in Australia; in 2019 they tripled to 6,718, but market share was just 0.6%.

✅ Sales rose from 2,216 (2018) to 6,718 (2019); ~80% were BEVs.

✅ Public charging sites reached 2,307; fast chargers up 40% year-on-year.

✅ Policy gaps and absent standards limit model supply and EV uptake.

 

Sales of electric vehicles in Australia tripled in 2019 despite a lack of government support, according to the industry’s peak body.

The country’s network of EV charging stations was also growing, the Electric Vehicle Council’s annual report found, including a rise in the number of faster charging stations that let drivers recharge a car in about 15 minutes.

But the report, released on Wednesday, found the market share for electric vehicles was still only 0.6% of new vehicle sales – well behind the 2.5% to 5% in other developed countries.

The chief executive of the council, Behyad Jafari, said the rise in sales was down to more models becoming available. There are now 28 electric models on sale, with eight priced below $65,000.

Six more were due to arrive before the end of 2021, including two priced below $50,000, the council’s report said.

“We have repeatedly heard from car companies that they were planning to bring vehicles here, but Australia doesn’t have that policy support.”

The Morrison government promised a national electric vehicle strategy would be finalised by the middle of this year, but the policy has been delayed. The prime minister, Scott Morrison, last year accused Labor of wanting to “end the weekend” and force people out of four-wheel drives after the opposition set a target of 50% of new car sales being electric by 2030.

Jafari cited the Kia e-Niro – an award-winning electric SUV that was being prepared for an Australian launch, but is now reportedly on hold because the manufacturer favoured shipping to countries with emissions standards.

The council’s members include BMW, Nissan, Hyundai and Harley Davidson, as well as energy, technology and charging infrastructure companies.

Sales of electric vehicles – which include plug-in hybrids – went from 2,216 in 2018 to 6,718 in 2019, the report said. Jafari said about 80% of those sales were all-electric vehicles.

There have been 3,226 electric vehicles sold in 2020, the report said, despite an overall drop of 20% in vehicle sales due to the Covid-19 pandemic, while U.S. EV sales have surged into 2024.

Jafari said: “Our report is showing that Australian consumers want these cars.

“There is no controversy that the future of the industry is electric, but at the moment the industry is looking at different markets. We want policies that show [Australia] is going on this journey.”

Government agency data has forecast that half the new cars sold will be electric by 2035, underscoring that the age of electric cars is arriving even if there is no policy to support their uptake.

Manufacturers currently selling electric cars in Australia are Nissan, Hyundai, Mitsubishi, Tesla, Volvo, Porsche, Audi, BMW, Mercedes, Jaguar and Renault, the report said.

Jafari said most G20 countries had emissions standards in place for vehicles sold and incentives in place to support electric vehicles, such as rebates or exemptions from charges. This hadn’t happened in Australia, he said.

The report said: “Globally, carmakers are rolling out more electric vehicle models as the electric car market expands, but so far production cannot keep up with demand. This means that without policy signals, Australians will continue to be denied access to the full global range of electric vehicles.”

On Tuesday, one Australian charging provider, Evie Networks, opened an ultra-fast station at a rest stop at Campbell Town in Tasmania – between Launceston and Hobart.

The company said the station would connect EV owners in the state’s north and south and the two 350kW chargers could recharge a vehicle in 15 minutes, highlighting whether grids have the power to charge EVs at scale. Two more sites were planned for Tasmania, the company said.

A Tasmanian government grant to support electric vehicle charging had helped finance the site. Evie was also supported with a $15m grant from the federal government’s Australian Renewable Energy Agency.

According to the council report, Australia now has 2,307 public charging stations, including 357 fast chargers – a rise of 40% in the past year.

A survey of 2,900 people in New South Wales, the ACT, Victoria and South Australia, carried out by NRMA, RACV and RAA on behalf of the council, found the main barriers to buying an electric vehicle were concerns over access to charging points, higher prices and uncertainty over driving range.

Consumers favoured electric vehicles because of their environmental footprint, lower maintenance costs and vehicle performance.

The report said the average battery range of electric vehicles available in Australia was 400km, but almost 80% of people thought the average was less.

According to the survey, 56% of Australians would consider an electric car when they next bought a vehicle, and in the UK, EV inquiries soared during a fuel supply crisis.

“We are far behind, but it is surmountable,” Jafari said.

The council report also rated state and territories on the policies that supported its industry and found the ACT was leading, followed by NSW and Queensland.

A review of commercial electric vehicle use found public electric bus trials were planned or under way in Queensland, NSW, WA, Victoria and ACT. There are now more than 400,000 electric buses in use around the globe.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.