Otter Tail bills rise with wind power

By Associ


High Voltage Maintenance Training Online

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:
$599
Coupon Price:
$499
Reserve Your Seat Today
Otter Tail Power Co.'s North Dakota customers will see higher electric bills as the utility adds more wind power to its energy sources, state regulators say.

Beginning September 1, a separate charge assessed to ratepayers to pay for Otter Tail wind energy projects will increase the monthly bill by almost $1.40 for a residential customer who uses 750 kilowatt-hours of electricity, state Public Service Commission filings say.

For that customer, the wind energy charge would rise from $2.76 monthly to $4.13, an increase of almost 50 percent. The "renewable energy rider" is listed separately on customers' bills.

Commissioner Tony Clark said the charge is intended to allow Otter Tail Power to begin recouping development costs for wind projects. But it does have its drawbacks, Clark said.

"It makes wind perhaps look a little boutique, or that we're treating it a little different," he said. "It's certainly not intended to be that way."

Fergus Falls, Minn.-based Otter Tail Power has about 57,000 North Dakota electric customers. It serves the cities of Wahpeton, Devils Lake and Jamestown, as well as a number of rural communities.

About 18 percent of the utility's electricity comes from wind turbines, including power that Otter Tail buys from other sources, company spokeswoman Cris Kling said Thursday. Almost three-quarters of its power is generated by coal-fueled plants.

Otter Tail owns part of wind energy projects that were recently built near Langdon, in North Dakota's northeast corner, and Lake Ashtabula, near Valley City in Barnes County. The utility owns 40.5 megawatts of the Langdon wind farm's generating capacity, and 48 megawatts from the Lake Ashtabula project.

The completion of a third wind project, six miles north of Luverne in Griggs County, in east-central North Dakota, made another increase in the wind-energy charge necessary, Kling said.

Otter Tail owns 49.5 megawatts of the Luverne development, which is capable of generating 169.5 megawatts and began operating almost a year ago. Its majority owner is NextEra Energy Resources of Juno Beach, Fla., a company formerly known as FPL Energy.

Clark said the separate renewable energy charge may give customers a misleading picture about their electricity costs.

If Otter Tail did not develop wind energy supplies, the utility would probably have to buy power on the open market during times of high demand, Clark said. However, the savings it realizes from wind power are lumped with a general monthly adjustment on fuel costs that are part of customers' electric bills and are not specifically listed, he said.

Related News

"Kill the viability": big batteries to lose out from electricity grid rule change

AEMC Storage Charging Rules spark industry backlash as Tesla, Snowy Hydro, and investors warn transmission charges on batteries and pumped hydro could deter grid-scale storage, distort the National Electricity Market, and slow decarbonisation.

 

Key Points

AEMC Storage Charging Rules are proposals to bill grid storage for network use, shaping costs and investment.

✅ Charges apply when batteries draw power; double-charging concerns.

✅ Tesla and Snowy Hydro warn of reduced viability and delays.

✅ AEMO recommends exemptions; investors seek certainty.

 

Tesla, Snowy Hydro and other big suppliers of storage capacity on Australia’s main electricity grid warn proposed rule changes amount to a tax on their operations that will deter investors and slow the decarbonisation of the industry.

The Australian Energy Market Commission (AEMC) will release its final decision this Thursday on new rules for integrating batteries, pumped hydro and other forms of storage.

The AEMC’s draft decision, released in July, angered many firms because it proposed charging storage providers for drawing power, ignoring a recommendation by the Australian Electricity Market Operator (AEMO) that they be exempt.

Battery maker Tesla, which has supplied some of the largest storage to the National Electricity Market, said in a submission that the charges would “kill the commercial viability of all grid storage projects, causing inefficient investment in alternative network”, with consumers paying higher costs.

Snowy Hydro, which is building the giant Snowy 2 pumped storage project and already operates a smaller one, said in its submission the proposed changes if implemented would jeopardise investment.

“This is a major policy change, amounting to a tax on infrastructure critical to achieving a renewable future,” Snowy Hydro said.

AEMO itself argued it was important storage providers were not “disincentivised from connecting to the transmission network, as they generally provide a net benefit to the power system by charging at periods of low demand”.

Australia’s electricity grid faces economic and engineering challenges, similar to Ontario's storage push as it adjusts to the arrival of lower cost and also lower carbon alternatives to fossil fuels.

While rule changes are necessary to account for operators that can both draw from and supply power, how they are implemented can have long-lasting effects on the technologies that get encouraged or repelled, including control of EV charging issues, independent experts say.

“It doesn’t have to be this way,” said Bruce Mountain, director of the Victoria Energy Policy Centre. “In Britain, where the UK grid transformation is underway, the regulator dealing with the same issues has said that storage devices don’t pay the system charges when they withdraw electricity from the grid,” he said.

The prospect that storage operators will have to pay transmission charges could “drastically” affect their profitability since their business models rely on the difference between the price their pay for power and how much they can sell it for. Gas generators and network monopolies would benefit from the change, Mountain said.

Sign up to receive an email with the top stories from Guardian Australia every morning

An AEMC spokesperson said the commission had consulted widely, including from those who objected to the payment for transmission access.

“The market is moving towards a future that will be increasingly reliant on energy storage to firm up the growing volume of renewable energy and deliver on the increasing need for critical system security services, with examples such as EVs supporting grid stability in California as the ageing fleet of thermal generators retire,” the spokesperson said, declining to elaborate on the final ruling before it is published.

“The regulatory framework needs to facilitate this transition as the energy sector continues to decarbonise,” the official said.

AusNet, which operates the Victorian energy transmission grid, said that while “technological neutrality is paramount for battery and hybrid unit connections to both the distribution and transmission networks,” it did not back charging storage access to networks in all cases.

“[Ausnet] supports a clear exemptions framework for energy storage providers,” a spokesperson said. “We recommend that batteries and other hybrid facilities should have transmission use of system charges waived if they provide a net benefit to network customers.”

We are not aware of anyone that supports the charging storage access to networks in all circumstances.

“Batteries and hybrid facilities that consume energy from the network should be provided no preferential treatment relative to other customers and generators.”

Jonathan Upson, a principal at Strategic Renewable Consulting, though, said the AEMC wants electricity flowing through batteries to be taxed twice to pay network charges – once when the electricity charges the battery and then again when the same electricity is sent out by the battery an hour or two later but this time with customers paying.

“The AEMC’s draft decision has the identical rationale for eliminating franking credits on all dividends, resulting in double taxing of company profits,” he said.

Christiaan Zuur, director of energy transformation at the Clean Energy Council, said that while much of AEMC’s draft proposal was constructive, “those benefits are either nullified or maybe even outweighed” by uncertainty over charges.

“Risk perception” will be important since potential newcomers won’t be sure of what charges they will pay to connect to the grid and existing operators could have their connection agreements reopened, Zuur said.

“Investors focus on the potential risk. It does factor through to the integral costs for projects,” he said.

The outcome of new charges may prompt more people to put batteries on their premises and draw power from their own solar panels, Mountain said, with rising EV adoption introducing new grid challenges, cutting their reliance on a centralised network.

“Ironically, it encourages customers to depend less and less on the grid,” he said. “It’s almost like the capture of the dominant interests playing out over time at their own expense.”

Separately, the latest edition of the Clean Energy Council Confidence Index shows leadership by state governments is helping to shore up investor appetite for investing in renewable energy amid 2021 electricity lessons even with higher 2030 emissions reduction goals from the federal government.

Overall, investor confidence increased by a point in the last six months – from 6.3 to 7.3 out of 10 – following strong commitments and policy development from state governments, particularly on the east coast, the council said.

“The results of this latest survey illustrate the economic value in policy that lowers the emissions footprint of our electricity generation, supporting regional centres and creating jobs. Investors recognise the opportunities created by limiting global temperature rise to 1.5 degrees,” said council chief executive Kane Thornton.

Among the states, NSW, Victoria and Queensland led in terms of positive investor sentiment.

Correction: this article was amended on 30 November. An earlier version stated Ausnet supported charging storage for network access. A spokesperson said it backed a waiver on charges if certain conditions are met.        

 

Related News

View more

Irving Oil invests in electrolyzer to produce hydrogen from water

Irving Oil hydrogen electrolyzer expands green hydrogen capacity at the Saint John refinery with Plug Power technology, cutting carbon emissions, enabling clean fuel for buses, and supporting Atlantic Canada decarbonization and renewable grid integration.

 

Key Points

A 5 MW Plug Power unit at Irving's Saint John refinery producing low-carbon hydrogen via electrolysis.

✅ Produces 2 tonnes/day, enough to fuel about 60 hydrogen buses

✅ Uses grid power; targets cleaner supply via renewables and nuclear

✅ First Canadian refinery investing in electrolyzer technology

 

Irving Oil is expanding hydrogen capacity at its Saint John, N.B., refinery in a bid to lower carbon emissions and offer clean energy to customers.

The family-owned company said Tuesday it has a deal with New York-based Plug Power Inc. to buy a five-megawatt hydrogen electrolyzer that will produce two tonnes of hydrogen a day — equivalent to fuelling 60 buses with hydrogen — using electricity from the local grid and drawing on examples such as reduced electricity rates proposed in Ontario to grow the hydrogen economy.

Hydrogen is an important part of the refining process as it's used to lower the sulphur content of petroleum products like diesel fuel, but most refineries produce hydrogen using natural gas, which creates carbon dioxide emissions and raises questions explored in hydrogen's future for power companies in the energy sector.

"Investing in a hydrogen electrolyzer allows us to produce hydrogen in a very different way," Irving director of energy transition Andy Carson said in an interview.

"Instead of using natural gas, we're actually using water molecules and electricity through the electrolysis process to produce ... a clean hydrogen."

Irving plans to continue to work with others in the province to decarbonize the grid amid pressures like Ontario's push into energy storage as electricity supply tightens and ensure the electricity being used to power its hydrogen electrolyzer is as clean as possible, he said.

N.B. Power's electrical system includes 14 generating stations powered by hydro, coal, oil, wind, nuclear and diesel. The utility has committed to increasing its renewable energy sources and exploring innovations such as EV-to-grid integration piloted in Nova Scotia.

Irving said it will be the first oil refinery in Canada to invest in electrolyzer technology, as Ontario's Hydrogen Innovation Fund supports broader deployment nationwide.

The company said its goal is to offer hydrogen fuelling infrastructure in Atlantic Canada, complementing N.L.'s fast-charging network for EV drivers in the region.

"This kind of investment allows us to not just move to a cleaner form of hydrogen in the refinery. It also allows us to store and make hydrogen available to the marketplace," Carson said.

Federal watchdog warns Canada's 2030 emissions target may not be achievable
The hydrogen technology will help Irving "unlock pent up demand for hydrogen as an energy transition fuel for logistics organizations," he said.

Alberta also aims to expand its hydrogen production over the coming years, alongside British Columbia's $900 million hydrogen project moving ahead on the West Coast. 

Those plans lean on the development of carbon capture and storage (CCS) technology that aims to trap the emissions created when producing hydrogen from natural gas.

 

Related News

View more

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.”

 

 

Related News

View more

Ford announces an all-electric Transit cargo van

Ford Electric Transit is an all electric cargo van for US and Canada, launching 2021, with 4G LTE hotspot, fleet telematics, GPS tracking, and driver assistance safety tech; battery, range, and performance specs TBD.

 

Key Points

An all electric cargo van with fleet telematics, 4G LTE, and driver assistance features for US and Canada.

✅ 4G LTE hotspot, live GPS tracking, and diagnostics

✅ Fleet telematics and management tools for operations

✅ Driver assistance: AEB, lane keeping, and collision warning

 

Ford is making an all-electric version of its popular Transit cargo van for the US and Canadian markets, slated to be released in 2021, aligning with Ford’s EV manufacturing plans to scale production across North America. The company did not share any specifics about the van’s battery pack size, estimated range, or performance characteristics. Ford previously announced an electric Transit for the European market in 2019.

The new cargo van will come equipped with a 4G LTE hotspot and will be outfitted with a number of tech features designed for fleet managers, like live GPS tracking and diagnostics, mirroring moves by Volvo’s electric trucks aimed at connected operations. The electric Transit van will also be equipped with a number of Ford’s safety and driver assistance features, like collision warning and assist, automatic emergency braking, pedestrian detection, and automatic lane-keeping.

Ford said it didn’t have any news to share about an electric version of its Transit passenger van “at this time,” even as the market reaches an EV inflection point for adoption.

Ford’s Transit van is the bestselling cargo van in the US, though it has seen increased competition over the last few years from Mercedes-Benz, which recently refreshed its popular Sprinter van, while others pursue electrified freight like Tesla’s electric truck plans that expand options.

Mercedes-Benz has already unveiled an electric version of the Sprinter, which comes in two configurations, targeting delivery networks where UPS’s Tesla Semi orders signal growing demand. There’s a version with a 55kWh battery pack that can travel 168 kilometers (104 miles) on a full charge, and has a payload capacity of 891 kilograms (1,964 pounds). Mercedes-Benz is making a version with a smaller 41kWh battery pack that goes 115 kilometers (72 miles), but which can carry up to 1,045 (2,304 pounds). Both versions come with 10.5 cubic meters (370.8 cubic feet) of storage space.

Mercedes-Benz also announced the EQV concept a year ago, which is an electric van aimed at slightly more everyday use, reflecting broader people-moving trends as electric bus adoption faces hurdles worldwide. The company touted more promising specs with the slightly smaller EQV, saying it will get around 249 miles out of a 100kWh battery pack. Oh, and it has 200 horsepower on offer and will be equipped with the company’s MBUX infotainment system.

Another player in the space is EV startup Rivian, which will build 100,000 electric delivery vans for Amazon over the next few years. Ford has invested $500 million in Rivian, and the startup is helping build a luxury electric SUV for the automotive giant’s Lincoln brand, though the two van projects don’t seem to be related, as Ford and others also boost gas-electric hybrid strategies in the US. Ford is also collaborating with Volkswagen on commercial vans after the two companies formed a global alliance early last year.

 

Related News

View more

When will the US get 1 GW of offshore wind on the grid?

U.S. Offshore Wind Capacity is set to exceed 1 GW by 2024, driven by BOEM approvals, federal leases, and resilient supply chains, with eastern states scaling renewable energy, turbines, and content despite COVID-19 disruptions.

 

Key Points

Projected gigawatt-scale offshore wind growth enabled by BOEM approvals, federal leases, and East Coast state demand.

✅ 17+ GW leased; only 1,870 MW in announced first phases.

✅ BOEM approvals are critical to reach >1 GW by 2024.

✅ Local supply chains mitigate COVID-19 impacts and lower costs.

 

Offshore wind in the U.S. will exceed 1 GW of capacity by 2024 and add more than 1 GW annually by 2027, a trajectory consistent with U.S. offshore wind power trends, according to a report released last week by Navigant Research.

The report calculated over 17 GW of offshore state and federal leases for wind production, reflecting forecasts that $1 trillion offshore wind market growth is possible. However, the owners of those leases have only announced first phase plans for 1,870 MW of capacity, leaving much of the projects in early stages with significant room to grow, according to senior research analyst Jesse Broehl.

The Business Network for Offshore Wind (BNOW) believes it is possible to hit 1 GW by 2023-24, according to CEO Liz Burdock. While the economy has taken a hit from the coronavirus pandemic, she said the offshore wind industry can continue growing as "the supply chain from Asia and Europe regains speed this summer, and the administration starts clearing" plans of construction.

BNOW is concerned with the economic hardship imposed on secondary and tertiary U.S. suppliers due to the global spread of COVID-19.

Offshore wind has been touted by many eastern states and governors as an opportunity to create jobs, with U.S. wind employment expected to expand, according to industry forecasts. Analysts see the growing momentum of projects as a way to further lower costs by creating a local supply chain, which could be jeopardized by a long-term shutdown and recession.

"The federal government must act now — today, not in December — and approve project construction and operation plans," a recent BNOW report said. Approving any of the seven projects before BOEM, which has recently received new lease requests, currently would allow small businesses to get to work "following the containment of the coronavirus," but approval of the projects next year "may be too late to keep them solvent."

The prospects for maintaining momentum in the industry falls largely to the Department of the Interior's Bureau of Ocean Energy Management (BOEM). The industry cannot hit the 1 GW milestone without project approvals by BOEM, which is revising processes to analyze federal permit applications in the context of "greater build out of offshore wind capacity," according to its website.

"It is heavily dependent on the project approval success," Burdock told Utility Dive.

Currently, seven projects are awaiting determinations from BOEM on their construction operation plans in Massachusetts, New York, where a major offshore wind farm was recently approved, New Jersey and Maryland, with more to be added soon, a BNOW spokesperson told Utility Dive.

To date, only one project has received BOEM approval for development in federal waters, a 12 MW pilot by Dominion Energy and Ørsted in Virginia. The two-turbine project is a stepping stone to a commercial-scale 2.6 GW project the companies say could begin installation as soon as 2024, and gave the developers experience with the permitting process.

In the U.S., developers have the capacity to develop 16.9 GW of offshore wind in federal U.S. lease areas, even as wind power's share of the electricity mix surges nationwide, Broehl told Utility Dive, but much of that is in early stages. The Navigant report did not address any impacts of coronavirus on offshore wind, he said.

Although Massachusetts has legislation in place to require utilities to purchase 1.6 GW of wind power by 2026, and several other projects are in early development stages, Navigant expects the first large offshore wind projects in the U.S. (exceeding 200 MW) will come online in 2022 or later, and the first projects with 400 MW or more capacity are likely to be built by 2024-2025, and lessons from the U.K.'s experience could help accelerate timelines. The U.S. would add about 1.2 GW in 2027, Broehl said.

The federal leasing activities along with the involvement from Eastern states and utilities "virtually guarantees that a large offshore wind market is going to take off in the U.S.," Broehl said.

 

Related News

View more

COVID-19: Daily electricity demand dips 15% globally, says report

COVID-19 Impact on Electricity Demand, per IEA data, shows 15% global load drop from lockdowns, with residential use up, industrial and service sectors down; fossil fuel generation fell as renewables and photovoltaics gained share.

 

Key Points

An overview of how lockdowns cut global power demand, boosted residential use, and increased the renewable share.

✅ IEA review shows at least 15% dip in daily global electricity load

✅ Lockdowns cut commercial and industrial demand; homes used more

✅ Fossil fuels fell as renewables and PV generation gained share

 

The daily demand for electricity dipped at least 15 per cent across the globe, according to Global Energy Review 2020: The impacts of the COVID-19 crisis on global energy demand and CO2 emissions, a report published by the International Energy Agency (IEA) in April 2020, even as global power demand surged above pre-pandemic levels.

The report collated data from 30 countries, including India and China, that showed partial and full lockdown measures adopted by them were responsible for this decrease.

Full lockdowns in countries — including France, Italy, India, Spain, the United Kingdom where daily demand fell about 10% and the midwest region of the United States (US) — reduced this demand for electricity.

 

Reduction in electricity demand after lockdown measures (weather corrected)


 

Source: Global Energy Review 2020: The impacts of the COVID-19 crisis on global energy demand and CO2 emissions, IEA


Drivers of the fall

There was, however, a spike in residential demand for electricity as a result of people staying and working from home. This increase in residential demand, though, was not enough to compensate for reduced demand from industrial and commercial operations.

The extent of reduction depended not only on the duration and stringency of the lockdown, but also on the nature of the economy of the countries — predominantly service- or industry-based — the IEA report said.

A higher decline in electricity demand was noted in countries where the service sector — including retail, hospitality, education, tourism — was dominant, compared to countries that had industrial economies.

The US, for example — where industry forms only 20 per cent of the economy — saw larger reductions in electricity demand, compared to China, where power demand dropped as the industry accounts for more than 60 per cent of the economy.

Italy — the worst-affected country from COVID-19 — saw a decline greater than 25 per cent when compared to figures from last year, even as power demand held firm in parts of Europe during later lockdowns.

The report said the shutting down of the hospitality and tourism sectors in the country — major components of the Italian economy — were said to have had a higher impact, than any other factor, for this fall.

 

Reduced fossil fuel dependency

Almost all of the reduction in demand was reportedly because of the shutting down of fossil fuel-based power generation, according to the report. Instead, the share of electricity supply from renewables in the entire portfolio of energy sources, increased during the pandemic, reflecting low-carbon electricity lessons observed during COVID-19.

This was due to a natural increase in wind and photovoltaic power generation compared to 2019 along with a drop in overall electricity demand that forced electricity producers from non-renewable sources to decrease their supplies, before surging electricity demand began to strain power systems worldwide.

The Power System Operation Corporation of India also reported that electricity production from coal — India’s primary source of electricity — fell by 32.2 per cent to 1.91 billion units (kilowatt-hours) per day, in line with India's electricity demand decline reported during the pandemic, compared to the 2019 levels.

 

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

Download the 2025 Electrical Training Catalog

Explore 50+ live, expert-led electrical training courses –

  • Interactive
  • Flexible
  • CEU-cerified