Ontario power rates to vary, minister says

Work From Home Energy Consumption is driving higher electricity bills as residential usage rises. Smart meter data, ISO-New-England trends, and COVID-19 telecommuting show stronger power demand and sensitivity to utility rates across regions.

Key Points

Higher household electricity use from telecommuting, shifting load to residences and raising utility bills.

✅ Smart meters show 5-22 percent residential usage increases.

✅ Commercial demand fell as home cooling and IT loads rose.

✅ Utility rates and AC use drive bill spikes during summer.

Don't be surprised if your electric bills are looking higher than usual, with a sizable increase in the amount of power that you have used.

Summer traditionally is a peak period for electricity usage because of folks' need to run fans and air-conditioners to cool their homes or run that pool pump. But the arrival of the coronavirus and people working from home is adding to amount of power people are using.

Under normal conditions, those who work in their employer's offices might not be cooling their homes as much during the middle of the day or using as much electricity for lights and running computers.

For many, that's changed.

Estimates on how much of an increase residential electric customers are seeing as result of working from home vary widely.

ISO-New England, the regional electric grid operator, has seen a 3 percent to 5 percent decrease in commercial and industrial power demand, even as the grid overseer issued pandemic warnings nationally. The expectation is that much of that decrease translates into a corresponding increase in residential electricity usage.

But other estimates put the increase in residential electricity usage much higher. A Washington state company that makes smart electric meters, Itron, estimates that American households are using 5 percent to 10 percent more electricity per month since March, when many people began working from home as part of an effort to prevent the spread of the coronavirus.

Another smart metering company, Cambridge, Mass.-based Sense, found that average home electricity usage increased 22 percent in April compared to the same period in 2019, a reflection of people using more electricity while they stayed home. Based on its analysis of data from 5,000 homes across 30 states, Sense officials said a typical customer's monthly electric bill increased by between $22 and $25, with a larger increase for consumers in states with higher electricity rates.

Connecticut-specfic data is harder to come by.

Officials with Orange-based United Illuminating declined to provide any customer usage data, though, like others in the power industry, they did acknowledge that residential customers are using more electricity. And the state's other large electric distribution utility, Eversource, was unable to provide any recent data on residential electric usage. The company did tell Connecticut utility regulators there was a 3 percent increase in residential power usage for the week of March 21 compared to the week before.

Over the same time period, Eversource officials saw a 3 percent decrease in power usage by commercial and industrial customers.

Separately, nuclear plant workers raised concerns about pandemic precautions at some facilities, reflecting operational strains.

Alan Behm of Cheshire said he normally uses 597 kilowatt hours of electricity during an average month. But in April of this year, the amount of electricity he used rose by nearly 51 percent.

With many offices closed, the expense of heating, cooking and lighting is being shifted from employer to employee, and some utilities such as Manitoba Hydro have pursued unpaid days off to trim costs during the pandemic. And one remote work expert believes some companies are recognizing the burden those added costs are placing on workers -- and are trying to do something about it.

Technology giant Google announced in late May that it was giving employees who work from home $1,000 allowances to cover equipment costs and other expenses associated with establishing a home office.

Moe Vela, chief transparency officer for the New York City-based computer software company TransparentBusiness, said the move by Google executives is a savvy one.

"Google is very smart to have figured this out," Vela said. "This is what employees want, especially millenials. People are so much happier to be working remotely, getting those two to three hours back per day that some people spend getting to and from work is so much more important than a stipend."

Vela predicted that even after a vaccine is found for the corona virus, one of the key worklife changes is likely to be a broader acceptance of telework and working from home.

Beyond the immediate shifts, more young Canadians would work in electricity if awareness improved, pointing to future talent pipelines.

"I think that's where we're headed," he said. "I think it will make an employer more attractive as they try to attract talent from around the world."

Vela said employers save an average of $11,000 per year for each employee they have working from home.

"It would be a brilliant move if a company were to share some of that amount with employees," he said. "I wouldn't do it if it's going to cause a company to not be there (in business) though."

The idea of a company sharing whatever savings it achieves by having employees work from home wasn't well received by many Connecticut residents who responded to questions posed via social media by Hearst Connecticut Media. More than 100 people responded and an overwhelming number of people spoke out against the idea.

"You are saving on gas and other travel related expenses, so the small increase in your electric bill shouldn't really be a concern," said Kathleen Bennett Charest of Wallingford.

Jim Krupp, also of Wallingford, said, "to suggest that the employers compensate the employees makes as much sense as suggesting that the employees should take a pay cut due to their reduced expenses for travel, day care, and eating lunch at work."

"Employers must still maintain their offices and incur all of the fixed expenses involved, including basic utilities, taxes and insurance," Krupp said. "The cost savings (for employers) that are realized are also offset by increased costs of creating and maintaining IT networks that allow employees to access their work sites from home and the costs of monitoring and managing the work force."

Kiki Nichols Nugent of Cheshire said she was against the idea of an employee trying to get their employer to pay for the increased electricity costs associated with working from home.

"I would not nickle and dime," Nugent said. "If companies are saving on electricity now, maybe employers will give better raises next year."

New Haven resident Chris Smith said he is "just happy to have a job where I am able to telecommute."

"When teleworking becomes more the norm, either now or in the future, we may see increased wages for teleworkers either for the lower cost to the employer or for the increase in productivity it brings," Smith said.

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TotalEnergies Africa Energy Strategy 2025 spotlights oil, gas, LNG, and renewables, with investments in Namibia, Congo, Mozambique, Uganda, Morocco, and South Africa, driving upstream growth, clean energy, and energy transition partnerships.

Key Points

An investment roadmap uniting oil, gas, LNG, and renewables to speed Africa's upstream growth and energy transition.

✅ Keynote by Mike Sangster at IAE Paris 2025.

✅ Oil, gas, LNG projects across Namibia, Congo, Mozambique, Uganda.

✅ Scaling renewables: solar, wind, green ammonia for export.

Mike Sangster, Senior Vice President for Africa at TotalEnergies, will play a pivotal role in the upcoming Invest in African Energy (IAE) Forum, which will take place in Paris on May 13-14, 2025. As a key figure in one of the world’s largest energy companies, Sangster's participation in the forum is expected to offer crucial insights into Africa’s evolving energy landscape, particularly in the areas of oil, gas, and renewable energy.

TotalEnergies' Role in Africa's Energy Landscape

TotalEnergies has long been a major player in Africa’s energy sector, driving development across both emerging and established markets. The company has a significant footprint in countries such as Namibia, the Republic of Congo, Libya, Mozambique, Uganda, and South Africa. TotalEnergies’ investments span both traditional oil and gas projects as well as renewable energy initiatives, reflecting its commitment to a more diversified energy future for Africa.

In Namibia, for instance, TotalEnergies is advancing its Venus-1 discovery, with plans to produce its first oil by the end of the decade. The company is also heavily involved in the Orange Basin exploration. Meanwhile, in the Republic of Congo, TotalEnergies is investing $600 million to enhance deepwater production at its Moho Nord field.

Beyond oil and gas, the company is expanding its renewable energy portfolio across the continent. This includes significant solar, wind, and hydropower projects, such as the 500 MW Sadada solar project in Libya, a 216 MW solar plant with battery storage in South Africa, and a 1 GW wind and solar project in Morocco designed to produce green ammonia for export.

The Invest in African Energy Forum

The IAE Forum, which TotalEnergies’ Sangster will headline, is an exclusive event aimed at facilitating investment between African energy markets and global investors, including discussions on COVID-19 funding for electricity access mechanisms that emerged, and their relevance to current capital flows. With a focus on fostering partnerships and discussions about the future of energy in Africa, the event will bring together industry experts, project developers, investors, and policymakers for two days of intensive engagement.

The forum will also serve as a crucial platform for sharing perspectives on the role of private investment, as outlined in the IEA investment outlook for Africa's power systems, in Africa’s energy future, strategies for unlocking new upstream opportunities, and the transition to a more sustainable energy system. This makes Sangster's participation, as someone directly involved in both conventional and renewable energy projects across the continent, particularly significant.

TotalEnergies' Diversified Strategy in Africa

Sangster’s keynote address and participation in an exclusive fireside chat will provide an in-depth look into TotalEnergies’ strategy for Africa. His insights will touch upon the company's ongoing projects in the oil and gas sectors, as well as its renewable energy investments. TotalEnergies has committed to making its portfolio more sustainable, underscored by its recent VSB acquisition to expand renewables capabilities, while continuing to be a leader in the energy transition.

One of the company’s notable projects is the Mozambique LNG initiative, a $20 billion venture aimed at supplying liquefied natural gas to international markets. Additionally, TotalEnergies is gearing up for the first oil from its Tilenga field in Uganda, which will be transported through the East African Crude Oil Pipeline (EACOP), the longest heated crude oil pipeline in the world.

In South Africa, TotalEnergies is constructing one of the largest renewable energy projects, a 216 MW solar power plant with integrated battery storage. This project is expected to significantly contribute to the country’s clean energy ambitions. Furthermore, in Morocco, TotalEnergies is developing a major wind and solar facility that will produce green ammonia, aligning with its broader strategy to provide solutions for Europe’s energy needs.

Africa’s Energy Transition

The forum’s timing could not be more critical, given the pressing need for an energy transition in Africa. While the continent remains heavily reliant on fossil fuels for its energy needs, there is growing momentum toward incorporating renewable energy sources, a point reinforced by the IRENA renewables report on decarbonisation and quality of life, which highlights the transformative potential. Africa’s vast natural resources, combined with global investments and partnerships, position the continent as a key player in the global shift toward sustainable energy.

However, Africa faces unique challenges in transitioning to renewable energy, reflecting a broader Sub-Saharan electricity challenge that also presents opportunity, across many markets. These challenges include a lack of infrastructure, financial constraints, and the need for increased political stability in certain regions. The IAE Forum provides an opportunity to address these barriers, with industry leaders like Sangster offering solutions based on real-world experiences and investments.

As the energy sector continues to evolve globally, and even if electricity systems are unlikely to go fully green this decade according to some outlooks, Africa's potential remains vast. The continent’s diverse energy resources, from oil and gas to renewables, offer a unique opportunity to build a more sustainable and resilient energy future. The Invest in African Energy Forum serves as an important platform for global stakeholders to collaborate, learn, and invest in the energy transformation taking place across the continent.

Mike Sangster’s insights at the forum will undoubtedly shape discussions on how companies like TotalEnergies are navigating the intersection of universal electricity access goals, sustainability, and economic growth in Africa. With Africa’s energy needs expected to increase exponentially in the coming decades, ensuring that these needs are met sustainably and equitably will be a priority for both policymakers and private investors.

As the global energy landscape continues to shift, the Invest in African Energy Forum provides a critical space for shaping the future of Africa’s energy sector, offering invaluable opportunities for investment, innovation, and collaboration.

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Hinkley Point C dome lift marks a nuclear reactor milestone in Somerset, as EDF used Big Carl crane to place a 245-tonne steel roof, enabling 2027 startup amid costs, delays, and precision indoor welding.

Key Points

A 245-tonne dome lifted onto Hinkley Point C's first reactor, finishing the roof and enabling fit-out for a 2027 startup.

✅ 245-tonne steel dome lifted by Big Carl onto 44m-high reactor

✅ Indoor welding avoided weather defects seen at Flamanville

✅ Cost now £33bn; first power targeted by end of 2027

Engineers have lifted a steel roof onto a building which will house the first of two nuclear reactors at Hinkley Point in Somerset.

Hundreds of people helped with the delicate operation to get the 245-tonne steel dome into position.

It means the first reactor can be installed next year, ready to be switched on in June 2027.

Engineers at EDF said the "challenging job" was completed in just over an hour.

They first broke the ground on the new nuclear station in March 2017. Now, some 10,000 people work on what is Europe's largest building site.

Yet many analysts note that Europe is losing nuclear power even as demand for reliable energy grows.

They have faced delays from Covid restrictions and other recent setbacks, and the budget has doubled to £33bn, so getting the roof on the first of the two reactor buildings is a big deal.

EDF's nuclear island director Simon Parsons said it was a "fantastic night".

"Lifting the dome into place is a celebration of all the work done by a fantastic team. The smiles on people's faces this morning were something else.

"Now we can get on with the fitting of equipment, pipes and cables, including the first reactor which is on site and ready to be installed next year."

Nuclear minister Andrew Bowie hailed the "major milestone" in the building project, citing its role in the UK's green industrial revolution ambitions.

He said: "This is a key part of the UK Government's plans to revitalise nuclear."

But many still question whether Hinkley Point C will be worth all the money, especially after Hitachi's project freeze in Britain, with Roy Pumfrey of the Stop Hinkley campaign describing the project as "shockingly bad value".

Why lift the roof on?

The steel dome is bigger than the one on St Paul's Cathedral in London.

To lift it onto the 44-metre-high reactor building, they needed the world's largest land-based crane, dubbed Big Carl by engineers.

So why not just build the roof on top of the building?

The answer lies in a remote corner of Normandy in France, near a village called Flamanville.

EDF has been building a nuclear reactor there since 2007, ten years before they started in west Somerset.

The project is now a decade behind schedule and has still not been approved by French regulators.

Why? Because of cracks found in the precision welding on the roof of the reactor building.

In nuclear-powered France, they built the roof in situ, out in the open. 

Engineers have decided welding outside, exposed to wind and rain, compromised the high standards needed for a nuclear reactor.

So in Somerset they built a temporary workshop, which looks like a fair sized building itself. All the welding has been done inside, and then the completed roof was lifted into place.

Is it on time or on budget?

No, neither. When Hinkley C was first approved a decade ago, EDF said it would cost £14bn.

Four years later, in 2017, they finally started construction. By now the cost had risen to £19.5bn, and EDF said the plant would be finished by the end of 2025.

Today, the cost has risen to £33bn, and it is now hoped Hinkley C will produce electricity by the end of 2027.

"Nobody believes it will be done by 2027," said campaigner Roy Pumfrey.

"The costs keep rising, and the price of Hinkley's electricity will only get dearer," they added.

On the other hand, the increase in costs is not a problem for British energy bill payers, or the UK government.

EDF agreed to pay the full cost of construction, including any increases.

When I met Grant Shapps, then the UK Energy Secretary, at the site in April, he shrugged off the cost increases.

He said: "I think we should all be rather pleased it is not the British tax payer - it is France and EDF who are paying."

In return, the UK government agreed a set rate for Hinkley's power, called the Strike Price, back in 2013. The idea was this would guarantee the income from Hinkley Point for 35 years, allowing investors to get their money back.

Will it be worth the money?

Back in 2013, the Strike Price was set at £92.50 for each megawatt hour of power. At the time, the wholesale price of electricity was around £50/MWh, so Hinkley C looked expensive.

But since then, global shocks like the war in Ukraine have increased the cost of power substantially, and advocates argue next-gen nuclear could deliver smaller, cheaper, safer designs.

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Mexico Energy Reform Defeat underscores opposition unity as CFE-first rules, state regulators, and lithium nationalization falter amid USMCA concerns, investment risks, and clean energy transition impacts in Congress over power generation policy.

Key Points

The failed push to expand CFE control, flagged for USMCA risks, higher costs, regulator shifts, and slower clean energy transition.

✅ Bill to mandate 54% CFE generation and priority dispatch failed.

✅ Opposition cited USMCA breaches, higher prices, slower clean energy.

✅ Lithium nationalization to return via separate legislation.

Mexican President Andres Manuel Lopez Obrador's plan to increase state control of power generation was defeated in parliament on Sunday, as opposition parties united in the face of a bill they said would hurt investment and breach international obligations, concerns mirrored by rulings such as the Florida court on electricity monopolies that scrutinize market concentration.

His National Regeneration Movement (MORENA) and its allies fell nearly 60 votes short of the two-thirds majority needed in the 500-seat lower house of Congress, mustering just 275 votes after a raucous session that lasted more than 12 hours.

Seeking to roll back previous constitutional reforms that liberalized the electricity market, Lopez Obrador's proposed changes would have done away with a requirement that state-owned Comision Federal de Electricidad (CFE) sell the cheapest electricity first, a move reminiscent of debates when energy groups warned on pricing changes under federal proposals, allowing it to sell its own electricity ahead of other power companies.

Under the bill, the CFE would also have been set to generate a minimum of 54% of the country's total electricity, and energy regulation would have been shifted from independent bodies to state regulators, paralleling concerns raised when a Calgary retailer opposed a market overhaul over regulatory impacts.

The contentious proposals faced much criticism from business groups and the United States, Mexico's top trade partner as well as other allies who argued it would violate the regional trade deal, the United States-Mexico-Canada Agreement (USMCA), even as the USA looks to Canada for green power to deepen cross-border energy ties.

Lopez Obrador had argued the bill would have protected consumers and made the country more energy independent, echoing how Texas weighs market reforms to avoid blackouts to bolster reliability, saying the legislation was vital to his plans to "transform" Mexico.

Although the odds were against his party, he came into the vote seeking to leverage his victory in last weekend's referendum on his leadership.

Speaking ahead of the vote, Jorge Alvarez Maynez, a lawmaker from the opposition Citizens' Movement party, said the proposals, if enacted, would damage Mexico, pointing to experiences like the Texas electricity market bailout after a severe winter storm as cautionary examples.

"There isn't a specialist, academic, environmentalist or activist with a smidgen of doubt - this bill would increase electricity prices, slow the transition to (clean) energy in our country and violate international agreements," he added.

Supporters of clean-energy goals noted that subnational shifts, such as the New Mexico 100% clean electricity bill can illustrate alternative pathways to reform.

The bill also contained a provision to nationalize lithium resources.

Lopez Obrador said this week that if the bill was defeated, he would send another bill to Congress on Monday aiming to have at least the lithium portion of the proposed legislation passed.

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NB Power Smart Meter Opt-Out Fees reflect cost causation principles set before the Energy and Utilities Board, covering meter reading charges, transmitter-disable options, rollout targets, and education plans across New Brunswick's smart metering program.

Key Points

Fees NB Power may apply to customers opting out of smart meters, reflecting cost causation and meter-reading costs.

✅ Based on cost causation and meter reading expenses

✅ BC and Quebec charge monthly opt-out surcharges

✅ Policy finalized during rollout after EUB review

NB Power customers who do not want a smart meter installed on their home could be facing a stiff fee for that decision, but so far the utility is not saying how much it might be.  

"It will be based on the principles of cost causation, but we have not gotten into the detail of what that fee would be at this point," said NB Power Senior Vice President of Operations Lori Clark at Energy and Utilities Board hearings on Friday.

In other jurisdictions that have already adopted smart meters, customers not wanting to participate have faced hundreds of dollars in extra charges, while Texas utilities' pullback from smart-home networks shows approaches can differ.

In British Columbia, power customers are charged a meter reading fee of $32.40 per month if they refuse a smart meter, or $20 per month if they accept a smart meter but insist its radio transmitter be turned off. That's a cost of between $240 and $388.80 per year for customers to opt out.

In Quebec, smart meters were installed beginning in 2012. Customers who refused the devices were initially charged $98 to opt out plus a meter reading fee of $17 per month. That was eventually cut by Quebec's energy board in 2014 to a $15 refusal fee and a $5 per month meter reading surcharge.

NB Power said it may be a year or more before it settles on its own fee.

"The opt out policy will be developed and implemented as part of the roll out.  It will be one of the last things we do," said Clark.

Customers need to be on board

NB Power is in front of the New Brunswick Energy and Utilities Board seeking permission to spend $122.7 million to install 350,000 smart meters province wide, as neighboring markets grapple with major rate increases that heighten affordability concerns.  

The meters are capable of transmitting consumption data of customers back to NB Power in real time, which the utility said will allow for a number of innovations in pricing and service, and help address old meter inaccuracies that affected some households.

The meters require near universal adoption by customers to maximize their financial benefit — like eliminating more than $20 million a year NB Power currently spends to read meters manually. The utility has said the switch will not succeed if too many customers opt out.

"We certainly wouldn't be looking at making an investment of this size without having the customer with us," said Clark.

On Thursday, Kent County resident Daniel LeBlanc, who along with Roger Richard, is opposing the introduction of smart meters for health reasons, predicted a cool reception for the technology in many parts of the province, given concerns that include health effects and billing disputes in Nova Scotia reported elsewhere.

"If one were to ask most of the people in the rural areas, I'm not sure you would get a lot of takers for this infrastructure," said LeBlanc, who is concerned with the long-term effect microwave frequencies used by the meters to transmit data may have on human health.

That issue is before the EUB next week.

Haven't tested the waters

NB Power acknowledged it has not measured public opinion on adopting smart meters but is confident it can convince customers it is a good idea for them and the utility, even as seasonal rate proposals in New Brunswick have prompted consumer backlash.

"People don't understand what the smart meter is," said Clark. "We need to educate our customers first to allow them to make an informed decision so that will be part of the roll out plan."

Clark noted that smart meters, helped by stiff opting out penalties, were eventually accepted by 98 per cent of customers in British Columbia and by 97.4 per cent of customers in Quebec.

"We will check and adjust along the way if there are issues with customer uptake," said Clark.

"This is very similar to what has been done in other jurisdictions and they haven't had those challenges."

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German Energy Price Brakes harness price signals in a market-based policy, cutting gas consumption, preserving industrial output, and supporting CO2 reduction, showcasing Germany's resilience and adaptation while protecting households and businesses across Europe.

Key Points

Fixed-amount subsidies preserving price signals to curb gas use, shield consumers, and sustain industrial output.

✅ Maintains incentives via market-based price signals

✅ Cuts gas consumption without distorting EU markets

✅ Protects households and industry while curbing CO2

German industry and society are once again proving much more resilient and adaptable than certain people feared. Horror scenarios of a dangerous energy rationing or a massive slump in our economy have often been bandied about. But we are nowhere near that. With a challenging year just behind us, this is good news — not only for Germany, but also for Europe, where France-Germany energy cooperation has strengthened solidarity.

Companies and households reacted swiftly to the sharp increases in energy prices, in line with momentum in the global energy transition seen across markets. They installed more efficient heating or production facilities, switched to alternatives and imported intermediate products. The results are encouraging: German households and businesses have reduced gas consumption significantly, despite recent cold weather. From the start of the war in Ukraine to mid-December industrial gas consumption in Germany was (temperature-adjusted) around 20 per cent lower than the average level for the preceding three years. Even if some firms have cut back production, especially in energy-intensive sectors, industrial output as a whole has only fallen by about 1 per cent since the start of 2022. Added to this, in a survey released by the Ifo institute in November, over a third of German companies saw the potential to reduce gas consumption further without endangering output.

Instead of imposing excessive laws and regulations, we have relied on price signals and the prudence of market participants to create the right incentives and reduce gas consumption, as falling costs like record-low solar power prices continue to reinforce those signals across sectors.

We will follow this approach in coming months, when energy savings will remain important, even as the EU electricity outlook anticipates sharply higher demand by 2050. Our latest relief measures will not distort price signals. To this end, the Bundestag approved gas and electricity price brakes in its final session in 2022. They are designed to function without any intervention in markets or prices. This system will pay out a fixed amount relative to previous years’ consumption and the current difference to a reference price — regardless of current consumption.

Energy price brakes are the main component of Germany’s “protective shield”, which makes up to €200bn available for measures in 2022 to 2024. Seen in relation to the German economy’s size, its past heavy reliance on Russian energy imports and the fact that the measures will expire in 2024, these are balanced and expedient mechanisms. In contrast to instruments used in other countries, our new arrangements will not affect the price formation process driven by supply and demand, or on incentives to save gas. Companies and households will continue to save the full market price when they reduce consumption by a unit of gas or electricity. In this way, the price brakes also avoid the creation of additional demand for gas at the expense of consumers in other European countries, even as Europe’s Big Oil turning electric signals broader structural shifts in energy markets. No one need fear that competition will be distorted or that gas will be bought up. Indeed, a recent IMF working paper on cushioning the impact of high energy prices on households explicitly praises the German energy price brakes.

Current developments confirm the effectiveness of a market-based approach — and show that we should also rely on price signals when it comes to reducing CO₂ emissions, as suggested by IEA CO2 trends in recent years. Last year, households and companies had only a few weeks to adapt, yet we have already seen a strong response. The effect of CO₂ prices can be even stronger, as adaptation is possible over a much longer time and they additionally affect expectations and long-term decisions. Regulatory interventions and subsidy schemes, even if well targeted, cannot compete with market co-ordination and incentives that support individual decision-making and promote innovation.

Europe and Germany can weather this crisis without a collapse in industrial production. We also have an opportunity to deal efficiently with the move to climate neutrality, aligned with Germany’s hydrogen strategy for imported low-carbon fuels. In both cases, we should have confidence in price signals as well as in the power of people and business to innovate and adapt.

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