FPL gives homeowners an energy makeover

Vehicle-to-Grid (V2G) enables EV batteries to provide grid balancing, flexibility, and demand response, integrating renewables with bidirectional charging, reducing peaker plant reliance, and unlocking distributed energy storage from millions of connected electric vehicles.

Key Points

Vehicle-to-Grid (V2G) lets EVs export power via bidirectional charging to balance grids and support renewables.

✅ Turns parked EVs into distributed energy storage assets

✅ Delivers balancing services and demand response to the grid

✅ Cuts peaker plant use and supports renewable integration

“There are already many Gigawatt-hours of batteries on wheels”, which could be used to provide balance and flexibility to electrical grids, if the “ultimate potential” of vehicle-to-grid (V2G) technology could be harnessed.

That’s according to a panel of experts and stakeholders convened by our sister site Current±, which covers the business models and technologies inherent to the low carbon transition to decentralised and clean energy. Focusing mainly on the UK grid but opening up the conversation to other territories and the technologies themselves, representatives including distribution network operator (DNO) Northern Powergrid’s policy and markets director and Nissan Europe’s director of energy services debated the challenges, benefits and that aforementioned ultimate potential.

Decarbonisation of energy systems and of transport go hand-in-hand amid grid challenges from rising EV uptake, with vehicle fuel currently responsible for more emissions than electricity used for energy elsewhere, as Ian Cameron, head of innovation at DNO UK Power Networks says in the Q&A article.

“Furthermore, V2G technology will further help decarbonisation by replacing polluting power plants that back up the electrical grid,” Marc Trahand from EV software company Nuvve Corporation added, pointing to California grid stability initiatives as a leading example.

While the panel states that there will still be a place for standalone utility-scale energy storage systems, various speakers highlighted that there are over 20GWh of so-called ‘batteries on wheels’ in the US, capable of powering buildings as needed, and up to 10 million EVs forecast for Britain’s roads by 2030.

“…it therefore doesn’t make sense to keep building expensive standalone battery farms when you have all this capacity on wheels that just needs to be plugged into bidirectional chargers,” Trahand said.

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Germany Nuclear Power Extension debated as Olaf Scholz weighs energy crisis, gas shortages from Russia, slow grid expansion in Bavaria, and renewables delays; stress test results may guide policy alongside coal plant reactivations.

Key Points

A proposal to delay Germany's nuclear phaseout to stabilize power supply amid gas cuts and slow grid upgrades.

✅ Driven by Russia gas cuts and Nord Stream 1 curtailment

✅ Targets Bavaria grid bottlenecks; renewables deployment delays

✅ Decision awaits grid stress test; coalition parties remain split

The German chancellor on Wednesday said it might make sense to extend the lifetime of Germany's three remaining nuclear power plants.

Germany famously decided to stop using atomic energy in 2011, and the last remaining plants were set to close at the end of this year.

However, an increasing number of politicians have been arguing for the postponement of the closures amid energy concerns arising from Russia's invasion of Ukraine. The issue divides members of Scholz's ruling traffic-light coalition.

What did the chancellor say?
Visiting a factory in western Germany, where a vital gas turbine is being stored, Chancellor Olaf Scholz was responding to a question about extending the lifetime of the power stations.

He said the nuclear power plants in question were only relevant for a small proportion of electricity production. "Nevertheless, that can make sense," he said.

The German government has previously said that renewable energy alternatives are the key to solving the country's energy problems.

However, Scholz said this was not happening quickly enough in some parts of Germany, such as Bavaria.

"The expansion of power line capacities, of the transmission grid in the south, has not progressed as quickly as was planned," the chancellor said.

"We will act for the whole of Germany, we will support all regions of Germany in the best possible way so that the energy supply for all citizens and all companies can be guaranteed as best as possible."

The phaseout has been planned for a long time. Germany's Social Democrat government, under Merkel's predecessor Gerhard Schröder, had announced that Germany would stop using nuclear power by 2022 as planned.

Schröder's successor Angela Merkel — herself a former physicist — had initially sought to extend to life of existing nuclear plants to as late as 2037. She viewed nuclear power as a bridging technology to sustain the country until new alternatives could be found.

However, Merkel decided to ditch atomic energy in 2011, after the Fukushima nuclear disaster in Japan, setting Germany on a path to become the first major economy to phase out coal and nuclear in tandem.

Nuclear power accounted for 13.3% of German electricity supply in 2021. This was generated by six power plants, of which three were switched off at the end of 2021. The remaining three — Emsland, Isar and Neckarwestheim — were due to shut down at the end of 2022. 

Germany's energy mix 1st half of 2022
The need to fill an energy gap has emerged after Russia dramatically reduced gas deliveries to Germany through the Nord Stream 1 pipeline, though nuclear power would do little to solve the gas issue according to some officials. Officials in Berlin say the Kremlin is seeking to punish the country — which is heavily reliant on Moscow's gas — for its support of Ukraine and sanctions on Russia.

Germany has already said it will temporarily fire up mothballed coal and oil power plants in a bid to solve the looming power crisis.

Social Democrat Scholz and Germany's energy minister, Robert Habeck, from the Green Party, a junior partner in the three-way coalition government, had previously ruled out any postponement of the nuclear phasout, despite debate over a possible resurgence of nuclear energy among some lawmakers. The third member of Scholz's coalition, the neoliberal Free Democrats, has voiced support for the extension, as has the opposition conservative CDU-CSU bloc.

Berlin has said it will await the outcome of a new "stress test" of Germany's electric grid before deciding on the phaseout.

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U.S. EV and Hybrid Sales 2024 show slower adoption versus gas-powered cars, as charging infrastructure gaps, range anxiety, higher upfront costs, and affordability concerns persist despite incentives, battery tech advances, and expanding fast-charging networks.

Key Points

They represent 10-15% of U.S. car sales, lagging gas models due to costs, charging gaps, range anxiety, and access.

✅ 10-15% of U.S. auto sales; gas cars dominate

✅ Barriers: upfront cost, limited charging, range anxiety

✅ Incentives, battery tech, and networks may boost adoption

Sales of hybrid and electric vehicles (EVs) in the U.S. are continuing to trail behind traditional gas-powered vehicles in 2024, despite significant advancements in automotive technology and growing public awareness of environmental concerns. While the electric vehicle market has seen steady growth and recent sales momentum over the past few years, the gap between EVs and gasoline-powered cars remains wide.

In 2024, hybrid and electric vehicles are projected to account for roughly 10-15% of total car sales in the U.S., a figure that, though significant, still lags far behind the sales of gas-powered vehicles and follows a Q1 2024 EV market share dip in the U.S., according to recent data. Analysts point to several factors contributing to this slower adoption rate, including higher upfront costs, limited charging infrastructure, and consumer concerns over range anxiety. Additionally, while EVs and hybrids offer lower lifetime operating costs, the initial price difference remains a hurdle for many prospective buyers.

One of the key challenges for EV sales continues to be the perception of cost, even as analyses show they can be better for the planet and often your budget over time. While federal and state incentives have made EVs more affordable, especially for lower-income buyers, the price tag for many electric models remains steep, particularly for higher-end vehicles. Even with government rebates, EVs can still be priced higher than their gasoline counterparts, making them less accessible for middle-class consumers. Many potential buyers are also hesitant to make the switch, unsure if the long-term savings will outweigh the initial investment.

Another critical factor is the limited charging infrastructure in many parts of the country. Though major cities have seen significant improvements in charging stations, rural areas and smaller towns still lack the necessary infrastructure to support widespread EV use. This uneven distribution of charging stations leads to concerns about being stranded in areas without access to fast-charging options. While automakers are working on expanding charging networks, the pace of this development is slow, and EVs won't go mainstream until key problems are fixed according to industry leaders.

Range anxiety is also a continuing issue, despite improvements in battery technology. Though newer electric vehicles can go further on a single charge than ever before, the range of many EVs still doesn't meet the expectations of some drivers, particularly those who regularly take long road trips or live in rural areas. The longer charging times and the necessity of planning routes around charging stations add to the hesitation, especially when gasoline-powered vehicles provide greater convenience and flexibility.

The shift toward EVs is further hindered by the continued dominance of gas-powered cars in the market. Gasoline vehicles benefit from decades of development, an extensive fueling infrastructure, and familiarity with the technology. For many consumers, the convenience, affordability, and ease of use of gas-powered vehicles still outweigh the benefits of switching to an electric alternative. Additionally, with fluctuating fuel prices, many drivers continue to find gas-powered cars relatively cost-effective in terms of daily commuting, especially when compared to the current costs of EV ownership.

Despite these challenges, there is hope for a future shift. The federal government’s push for stricter emissions regulations and tax incentives continues to fuel growth in the electric vehicle market. As automakers ramp up production and more affordable options become available, EV sales are expected to increase in the coming years. Companies like Tesla, Ford, whose hybrids are getting a boost, and General Motors are leading the charge, while new manufacturers like Rivian and Lucid Motors are offering alternatives to traditional gasoline vehicles.

Furthermore, the development of new technologies, such as solid-state batteries and faster charging systems, could help alleviate some of the current drawbacks of electric vehicles. If these advancements reach mass-market production in the next few years, they could help make EVs a more attractive and practical option for consumers, aligning with within-a-decade adoption forecasts from some industry observers.

In conclusion, while hybrid and electric vehicles are growing in popularity, gas-powered vehicles continue to dominate the U.S. car market in 2024. Challenges such as high upfront costs, limited charging infrastructure, and concerns about range persist, making it difficult for many consumers to make the switch to electric even as they ask if it's time to buy an EV in 2024. However, with continued investment in technology and infrastructure, the gap between EVs and gas-powered vehicles could narrow in the years to come.

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BC Hydro 2021 Peak Load Records highlight record-breaking electricity demand, peak load spikes, heat dome impacts, extreme cold, and shifting work-from-home patterns managed by a flexible hydroelectric system and climate-driven load trends.

Key Points

Record-breaking electricity demand peaks from extreme heat and cold that reshaped daily load patterns across BC in 2021.

✅ Heat dome and deep freeze drove sustained peak electricity demand

✅ Peak load built gradually, reflecting work-from-home behavior

✅ Flexible hydroelectric system adapts quickly to demand spikes

From June’s heat dome to December’s extreme cold, 2021 was a record-setting year, according to BC Hydro, and similar spikes were noted as Calgary's electricity use surged in frigid weather.

On Friday, the energy company released a new report on electricity demand, and how extreme temperatures over extended periods of time, along with growing scrutiny of crypto mining electricity use, led to record peak loads.

“We use peak loads to describe the electricity demand in the province during the highest load hour of each day,” Kyle Donaldson, BC Hydro spokesperson, said in a media release.

“With the heat dome in the summer and the sustained cold temperatures in December, we saw more record-breaking hours on more days last year than any other single year.”

According to BC Hydro, during summer, the Crown corporation recorded 19 of its top 25 all-time summer daily peak records — including breaking its all-time summer peak hourly demand record.

In December, which saw extremely cold temperatures and heavy snowfall, BC Hydro said its system experienced the highest and longest sustained load levels ever, as it activated its winter payment plan to assist customers.

Overall, BC Hydro says it has experienced 11 of its top 25 all-time daily peak records this winter, adding that Dec. 27 broke its all-time high peak hourly demand record.

“BC Hydro’s hydroelectric system is directly impacted by variations in weather, including drought conditions that require adaptation, and in 2021 more electricity demand records were broken than any other year prior, largely because of the back-to-back extreme temperatures lasting for days and weeks on end,” reads the report.

The energy company expects this trend to continue, noting that it has broken the peak record five times in the past five years, and other jurisdictions such as Quebec consumption record have also shattered consumption records.

It also noted that peak demand patterns have also changed since the first year of the COVID-19 pandemic, with trends seen during Earth Hour usage offering context.

“When the previous peak hourly load record was broken in January 2020, load displayed sharper increases and decreases throughout the day, suggesting more typical weather and behaviour,” said the report.

“In contrast, the 2021 peak load built up more gradually throughout the day, suggesting more British Columbians were likely working from home, or home for the holidays – waking up later and home earlier in the evening – as well as colder weather than average.”

BC Hydro also said “current climate models suggest a warming trend continuing in years to come which could increase demand year-round,” but noted that its flexible hydroelectric system can meet changes in demand quickly.

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Nova Scotia Power Rate Regulation explains how the privately owned utility is governed by the Utility Review Board, limiting government authority, while COVID-19 relief measures include suspended disconnections, waived fees, payment plans, and emergency assistance.

Key Points

URB oversight where the board, not the province, sets power rates, with COVID-19 relief pausing disconnections and fees.

✅ Province lacks authority to order rate cuts

✅ URB regulates Nova Scotia Power rates

✅ Relief: no disconnections, waived fees, payment plans

The province can't ask Nova Scotia Power to lower its rates to ease the financial pressure on out-of-work residents because it lacks the authority to take that kind of action, even as the Nova Scotia regulator approved a 14% hike in a separate proceeding, the provincial energy minister said Thursday.

Derek Mombourquette said he is in "constant contact" with the privately owned utility.

"The conversations are ongoing with Nova Scotia Power," he said after a cabinet meeting.

When asked if the Liberal government would order the utility to lower electricity rates as households and businesses struggle with the financial fallout from the COVID-19 pandemic, Mombourquette said there was nothing he could do.

"We don't have the regulatory authority as a government to reduce the rates," he told reporters during a conference call.

"They're independent, and they are regulated through the (Nova Scotia Utility Review Board). My conversations with Nova Scotia Power essentially have been to do whatever they can to support Nova Scotians, whether it's residents or businesses in this very difficult time."

Asked if the board would take action, the minister said: "I'm not aware of that," despite the premier's appeals to regulators in separate rate cases.

However, the minister noted that the utility, owned by Emera Inc., has suspended disconnections for bill non-payment for at least 90 days, a step similar to reconnection efforts by Hydro One announced in Ontario.

It has also relaxed payment timelines and waived penalties and fees, while some jurisdictions offered lump-sum credits to help with bills.

Nova Scotia Power CEO Wayne O'Connor has also said the company is making additional donations to a fund available to help low-income individuals and families pay their energy bills.

In late March, Ontario cut electricity rates for residential consumers, farms and small businesses in response to a surge in people forced to work from home as a result of the pandemic, alongside bill support measures for ratepayers.

Premier Doug Ford said there would be a 45-day switch to off-peak rates, later moving to a recovery rate framework, which meant electricity consumers would be paying the lowest rate possible at any time of day.

The change was expected to cost the province about $162 million.

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Hydro One CEO Mark Poweska aims to rebuild ties with Ontario's provincial government, investors, and communities, stabilize the executive team, boost earnings and dividends, and reset strategy after the scrapped Avista deal and regulatory setbacks.

Key Points

He plans to mend government and investor relations, rebuild the C-suite, and refocus growth after the failed Avista bid.

✅ Rebuild ties with Ontario government and regulators

✅ Stabilize executive team and governance

✅ Refocus growth after Avista deal termination

The incoming chief executive officer of Hydro One Ltd. said Thursday that he aims to rebuild the relationship between the Ontario electrical utility and the provincial government, as seen in COVID-19 support initiatives, as well as ties between the company and its investors.

Mark Poweska, the former executive vice-president of operations at BC Hydro, was announced as Hydro One’s new president and CEO in March. His hiring followed a turbulent period for Toronto-based Hydro One, Ontario’s biggest distributor and transmitter of electricity, with large-scale storm restoration efforts underscoring its role.

Hydro One’s former CEO and board of directors departed last year under pressure from a new Ontario government, the utility’s biggest shareholder. Earlier this year, the company’s plan for a $6.7-billion takeover fell apart over concerns of political interference and the utility clashed with the new provincial government and Progressive Conservative Premier Doug Ford over executive compensation levels, amid rate policy debates such as no peak rate cuts for self-isolating customers.

Hydro One facing $885 million charge as regulator upholds tax decision forcing it to share savings with customers

Shares of Hydro One were up more than eight per cent year-to-date on Wednesday, closing at $21.74. However, the stock price was up only six per cent from Hydro One’s 2015 initial public offering price, something its incoming CEO seems set on changing.

“One of my first priorities will be to solidify the executive team and build relationships with the Government of Ontario, our customers, informed by customer flexibility research, and communities, indigenous leaders, investors, and our partners across the electricity sector,” Poweska said Thursday on a conference call outlining Hydro One’s first-quarter results. “At the same time, I will be working to earn the trust and confidence of the investment community.”

Hydro One reported a profit of $171 million for the three months ended March 31, while peers such as Hydro-Québec reported pandemic-related losses as the sector adapted. Net income for the first quarter was down from $222 million a year earlier, which was due to $140 million in costs related to the scrapping of Hydro One’s proposed acquisition of U.S. energy company Avista Corp.

Hydro One Ltd. appointed Mark Poweska as President and CEO.

In January, Hydro One said the proposed takeover of Spokane, Wash.-headquartered Avista, an approximately $6.7-billion deal announced in July 2017, was being called off. As a result, Hydro One said it would pay Avista a US$103 million break fee.

Revenues net of purchased power for the first quarter rose to $952 million, up by 15.4 per cent compared to last year, Hydro One said, helped by higher distribution revenues. Adjusted profit for the quarter, which removes the Avista-related costs, was $311 million, up from $210 million a year ago.

The company is hiking its quarterly dividend to 24.15 cents per share, up five per cent from the last increase in May 2018, while also launching a pandemic relief fund for customers.

Poweska is taking over for acting president and CEO Paul Dobson this month, and the new executive will be charged with revamping Hydro One’s C-suite.

The company’s chief operating officer, chief legal officer, and chief corporate development officer have all departed this year. The company’s chief human resource officer has retired as well, although Poweska did announce Thursday that he had appointed acting chief financial officer Chris Lopez as CFO.

“Hydro One’s significant bench strength and management depth will ensure stability and continuity during this period of transition, as the sector pursues Hydro-Québec energy transition as well,” the company said in its first-quarter earnings press release.

Ontario remains Hydro One’s biggest shareholder, owning approximately 47 per cent of the company.

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