Pennsylvania law tries to cut power usage

B.C. EV Electrification 2055 projects grid capacity needs doubling to 37 GW, driven by electric vehicles, renewable energy expansion, wind and solar generation, limited natural gas, and policy mandates for zero-emission transportation.

Key Points

A projection that electrifying all B.C. road transport by 2055 would more than double grid demand to 37 GW.

✅ Site C adds 1.1 GW; rest from wind, solar, limited natural gas.

✅ Electricity price per kWh rises 9%, but fuel savings offset.

✅ Significant GHG cuts with 93% renewable grid under Clean Energy Act.

Researchers at the University of Victoria say that if B.C. were to shift to electric power for all road vehicles by 2055, the province would require more than double the electricity now being generated.

The findings are included in a study to be published in the November issue of the Applied Energy journal.

According to co-author and UVic professor Curran Crawford, the team at the university's Pacific Institute for Climate Solutions took B.C.'s 2015 electrical capacity of 15.6 gigawatts as a baseline, and added projected demands from population and economic growth, then added the increase that shifting to electric vehicles would require, while acknowledging power supply challenges that could arise.

They calculated the demand in 2055 would amount to 37 gigawatts, more than double 15.6 gigawatts used in 2015 as a baseline, and utilities warn of a potential EV charging bottleneck if demand ramps up faster than infrastructure.

"We wanted to understand what the electricity requirements are if you want to do that," he said. "It's possible — it would take some policy direction."

B.C. announces $4M in rebates for home and work EV charging stations across the province
The team took the planned Site C dam project into account, but that would only add 1.1 gigawatts of power. So assuming no other hydroelectric dams are planned, the remainder would likely have to come from wind and solar projects and some natural gas.

"Geothermal and biomass were also in the model," said Crawford, adding that they are more expensive electricity sources. "The model we were using, essentially, we're looking for the cheapest options."
Wind turbines on the Tantramar Marsh between Nova Scotia and New Brunswick tower over the Trans-Canada Highway. If British Columbia were to shift to 100 per cent electric-powered ground transportation by 2055, the province would have to significantly increase its wind and solar power generation. (Eric Woolliscroft/CBC)
The electricity bill, per kilowatt hour, would increase by nine per cent, according to the team's research, but Crawford said getting rid of the gasoline and diesel now used to fuel vehicles could amount to an overall cost saving, especially when combined with zero-emission vehicle incentives available to consumers.

The province introduced a law this year requiring that all new light-duty vehicles sold in B.C. be zero emission by 2040, while the federal 2035 EV mandate adds another policy signal, so the researchers figured 2055 was a reasonable date to imagine all vehicles on the road to be electric.

Crawford said hydrogen-powered vehicles weren't considered in the study, as the model used was already complicated enough, but hydrogen fuel would actually require more electricity for the electrolysis, when compared to energy stored in batteries.

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The study also found that shifting to all-electric ground transportation in B.C. would also mean a significant decrease in greenhouse gas emissions, assuming the Clean Energy Act remains in place, which mandates that 93 per cent of grid electricity must come from renewable resources, whereas nationally, about 18 per cent of electricity still comes from fossil fuels, according to 2019 data. 

"Doing the electrification makes some sense — If you're thinking of spending some money to reduce carbon emissions, this is a pretty cost effective way of doing that," said Crawford.

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Colorado Wildfire Power Shutoffs reduce ignition risk through PSPS, grid safety protocols, data-driven forecasts, and emergency coordination, protecting communities, natural resources, and infrastructure during extreme fire weather fueled by drought and climate change.

Key Points

Planned PSPS outages cut power in high-risk areas to prevent ignitions, protect residents, and boost wildfire resilience.

✅ PSPS triggered by forecasts, fuel moisture, and fire danger indices.

✅ Utilities coordinate alerts, timelines, and critical facility support.

✅ Paired with forest management, education, and rapid response.

Colorado, known for its stunning landscapes and outdoor recreation, has implemented proactive measures to reduce the risk of wildfires by strategically shutting off power in high-risk areas, similar to PG&E wildfire shutoffs implemented in California during extreme conditions. This approach, while disruptive, aims to safeguard communities, protect natural resources, and mitigate the devastating impacts of wildfires that have become increasingly prevalent in the region.

The decision to initiate power outages as a preventative measure against wildfires underscores Colorado's commitment to proactive fire management and public safety, aligning with utility disaster planning practices that strengthen grid readiness. With climate change contributing to hotter and drier conditions, the state faces heightened wildfire risks, necessitating innovative strategies to minimize ignition sources and limit fire spread.

Utility companies, in collaboration with state and local authorities, identify areas at high risk of wildfire based on factors such as weather forecasts, fuel moisture levels, and historical fire data. When conditions reach critical thresholds, planned power outages, also known as Public Safety Power Shutoffs (PSPS), are implemented to reduce the likelihood of electrical equipment sparking wildfires during periods of extreme fire danger, particularly during windstorm-driven outages that elevate ignition risks.

While power outages are a necessary precautionary measure, they can pose challenges for residents, businesses, and essential services that rely on uninterrupted electricity, as seen when a North Seattle outage affected thousands last year. To mitigate disruptions, utility companies communicate outage schedules in advance, provide updates during outages, and coordinate with emergency services to ensure the safety and well-being of affected communities.

The implementation of PSPS is part of a broader strategy to enhance wildfire resilience in Colorado. In addition to reducing ignition risks from power lines, the state invests in forest management practices, wildfire prevention education, and emergency response capabilities, including continuity planning seen in the U.S. grid COVID-19 response, to prepare for and respond to wildfires effectively.

Furthermore, Colorado's approach to wildfire prevention highlights the importance of community preparedness and collaboration, and utilities across the region adopt measures like FortisAlberta precautions to sustain critical services during emergencies. Residents are encouraged to create defensible space around their properties, develop emergency evacuation plans, and stay informed about wildfire risks and response protocols. Community engagement plays a crucial role in building resilience and fostering a collective effort to protect lives, property, and natural habitats from wildfires.

The effectiveness of Colorado's proactive measures in mitigating wildfire risks relies on a balanced approach that considers both short-term safety measures and long-term fire prevention strategies. By integrating technology, data-driven decision-making, and community partnerships, the state aims to reduce the frequency and severity of wildfires while enhancing overall resilience to wildfire impacts.

Looking ahead, Colorado continues to refine its wildfire management practices in response to evolving environmental conditions and community needs, drawing on examples of localized readiness such as PG&E winter storm preparation to inform response planning. This includes ongoing investments in fire detection and monitoring systems, research into fire behavior and prevention strategies, and collaboration with neighboring states and federal agencies to coordinate wildfire response efforts.

In conclusion, Colorado's decision to implement power outages as a preventative measure against wildfires demonstrates proactive leadership in wildfire risk reduction and public safety. By prioritizing early intervention and community engagement, the state strives to safeguard vulnerable areas, minimize the impact of wildfires, and foster resilience in the face of increasing wildfire threats. As Colorado continues to innovate and adapt its wildfire management strategies, its efforts serve as a model for other regions grappling with the challenges posed by climate change and wildfire risks.

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Municipal Renewable Energy Procurement surged as cities contracted 3.7 GW of solar and wind, leveraging green tariffs, community solar, and utility partnerships across the Southeast, led by Houston, RMI, and WRI data.

Key Points

The process by which cities contract solar and wind via utilities or green tariffs to meet climate goals.

✅ 3.7 GW procured in 2020, nearly 25% year-over-year growth

✅ Houston runs city ops on 500 MW solar, a record purchase

✅ Southeast cities use green tariffs and community solar

Cities around the country bought more renewable energy last year than ever before, reflecting how renewables may soon provide one-fourth of U.S. electricity across the grid, with some of the most remarkable projects in the Southeast, according to new data unveiled Thursday.

Even amid the pandemic, about eight dozen municipalities contracted to buy nearly 3.7 gigawatts of mostly solar and wind energy — enough to power more than 800,000 homes. The figure is almost a quarter higher than the year before.

Half of the cites listed as “most noteworthy” in Thursday’s release —  from research groups Rocky Mountain Institute and World Resources Institute — are in the region that stretches from Texas to Washington, D.C. 

Houston stands out for the sheer enormity of its purchase: In July, it began powering city operations entirely from nearly 500 megawatts of solar power — the largest municipal purchase of renewable energy ever in the United States, as renewable electricity surpassed coal nationwide.

The groups also feature smaller deals in North Carolina and Tennessee, achieved through a utility partnership called a green tariff.

“We wanted to recognize that Nashville and Charlotte were really blazing a new trail,” said Stephen Abbott, principal at the Rocky Mountain Institute.

And the nation’s capital shows how renewable energy can be a source of revenue: It’s leasing out its public transit station rooftops for 10 megawatts of community solar.

All of these strategies will be necessary for scores of U.S. cities to meet their ambitious climate goals, researchers believe. An interactive clean energy targets tracker shows all 95 clean energy procurements from the year in detail.

Tracker 
Even before former President Donald Trump promised to remove the United States from the Paris Climate Accord, a lack of federal action on climate left a void that some cities and counties were beginning to fill, as renewables hit a record 28% in a recent month. In 2015, the first year tracked by researchers at the Rocky Mountain Institute and the World Resources Institute, municipalities contracted to buy more than 1 gigawatt of wind, solar and other forms of clean energy. 

But when Trump officially set in motion the withdrawal from the climate agreement, the ranks of municipalities dedicated to 100% clean energy multiplied. Today there are nearly 200 of them. The growth in activity last year reflects, in part, that surge of new pledges.

“It takes a while to get city staff up to speed and understand the options, and create the roadmap and then start executing,” Abbott said. “There is a bit of a lag, but we’re starting to see the impact.”

Even in Houston — one of the earliest to begin procuring renewable energy — there has been a steep learning curve as market forces change and prices drop, including cheaper solar batteries shaping procurement strategies, said Lara Cottingham, Houston’s chief of staff and chief sustainability officer.

No matter how well resourced and educated their staff, cities have to clear a thicket of structural, political and economic challenges to procure renewable energy. Most don’t own their own sources of power. Nearly all face budget constraints. Few have enough land or government rooftops to meet their goals within city limits.

“Cities face a situation where it’s a square peg in a round hole,” Cottingham said.

The hurdles are especially steep in much of the Southeast, where only publicly regulated utilities can sell electricity to retail customers, even large ones such as major cities. That’s where a green tariff regime comes in: Cities can purchase clean energy from a third party, such as a solar company, using the utility as a go-between.

Early last year, Charlotte became the largest city to use such a program, partnering with Duke Energy and two North Carolina solar developers to build a solar farm 50 miles north in Iredell County. At first, the city will pay a premium for the energy, but in the latter half of the 20-year contract, as gas prices rise, it will save money compared to business as usual.

“Over the course of 20 years, it’s projected we would save about $2 million,” Katie Riddle, sustainability analyst with Charlotte, told the Energy News Network last year.

The growing size of projects, innovative partnerships like green tariff programs, and the improving economics all give Abbott hope that renewable energy investments from cities will only grow — even with the Trump presidency over and the country back in the Paris agreement.

And when cities meet their goals for procuring renewable energy for their own operations, they must then turn to an even bigger task: reducing the carbon footprint of every person in their jurisdiction with broader decarbonization strategies and community engagement.

“The city needs to do its part for sure,” said Houston’s Cottingham. “Then we have this challenge of how do we get everyone else to.”

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Germany Nuclear Phase-Out reflects a decisive energy policy shift, retiring reactors as firms shun new builds amid high costs, radioactive waste challenges, climate goals, insurance gaps, and debate over small modular reactors and subsidies.

Key Points

Germany's policy to end nuclear plants and block new builds, emphasizing safety, waste, climate goals, and viability.

✅ Driven by safety risks, waste storage limits, and insurance gaps

✅ High capital costs and subsidies make new reactors uneconomic

✅ Political debate persists; SMRs raise cost and proliferation concerns

A year has passed since Germany deactivated its last three nuclear power plants, marking a significant shift in its energy policy.

Nuclear fission once heralded as the future of energy in Germany during the 1960s, was initially embraced with minimal concern for the potential risks of nuclear accidents. As Heinz Smital from Greenpeace recalls, the early optimism was partly driven by national interest in nuclear weapon technology rather than energy companies' initiatives.

Jochen Flasbarth, State Secretary in the Ministry of Development, reflects on that era, noting Germany's strong, almost naive, belief in technology. Germany, particularly the Ruhr region, grappled with smog-filled skies at that time due to heavy industrialization and coal-fired power plants. Nuclear energy presented a "clean" alternative at the time.

This sentiment was also prevalent in East Germany, where the first commercial nuclear power plant came online in 1961. In total, 37 nuclear reactors were activated across Germany, reflecting a widespread confidence in nuclear technology.

However, the 1970s saw a shift in attitudes. Environmental activists protested the construction of new power plants, symbolizing a generational rift. The 1979 Three Mile Island incident in the US, followed by the catastrophic Chornobyl disaster in 1986, further eroded public trust in nuclear energy.

The Chornobyl accident, in particular, significantly dampened Germany's nuclear ambitions, according to Smital. Post-Chernobyl, plans for additional nuclear power plants in Germany, once numbering 60, drastically declined.

The emergence of the Green Party in 1980, rooted in anti-nuclear sentiment, and its subsequent rise to political prominence further influenced Germany's energy policy. The Greens, joining forces with the Social Democrats in 1998, initiated a move away from nuclear energy, facing opposition from the Christian Democrats (CDU) and Christian Social Union (CSU).

However, the Fukushima disaster in 2011 prompted a policy reversal from CDU and CSU under Chancellor Angela Merkel, leading to Germany's eventual nuclear phase-out in March 2023, after briefly extending nuclear power amid the energy crisis.

Recently, the CDU and CSU have revised their stance once more, signaling a potential U-turn on the nuclear phaseout, advocating for new nuclear reactors and the reactivation of the last shut-down plants, citing climate protection and rising fossil fuel costs. CDU leader Friedrich Merz has lamented the shutdown as a "black day for Germany." However, these suggestions have garnered little enthusiasm from German energy companies.

Steffi Lemke, the Federal Environment Minister, isn't surprised by the companies' reluctance, noting their longstanding opposition to nuclear power, which she argues would do little to solve the gas issue in Germany, due to its high-risk nature and the long-term challenge of radioactive waste management.

Globally, 412 reactors are operational across 32 countries, even as Europe is losing nuclear power during an energy crunch, with the total number remaining relatively stable over the years. While countries like China, France, and the UK plan new constructions, there's a growing interest in small, modern reactors, which Smital of Greenpeace views with skepticism, noting their potential military applications.

In Germany, the unresolved issue of nuclear waste storage looms large. With temporary storage facilities near power plants proving inadequate for long-term needs, the search for permanent sites faces resistance from local communities and poses financial and logistical challenges.

Environment Minister Lemke underscores the economic impracticality of nuclear energy in Germany, citing prohibitive costs and the necessity of substantial subsidies and insurance exemptions.

As things stand, the resurgence of nuclear power in Germany appears unlikely, with economic factors playing a decisive role in its future.

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bGen Thermal Energy Storage stores high-temperature heat in crushed rocks, enabling on-demand steam, hot water, or hot air; integrates renewables, shifts load with off-peak electricity, and decarbonizes campus heating at SUNY Purchase with NYPA.

Key Points

A rock-based TES system storing heat to deliver steam, hot water, or hot air using renewables or off-peak power.

✅ Uses crushed rocks to store high-temperature heat

✅ Cuts about 550 metric tons CO2 annually at SUNY Purchase

✅ Integrates renewables and off-peak electricity with NYPA

Brenmiller Energy Ltd. (NASDAQ: BNRG), in collaboration with the New York Power Authority (NYPA), a utility pursuing grid software modernization to improve reliability, has successfully deployed its first bGen™ thermal energy storage (TES) system in the United States at the State University of New York (SUNY) Purchase College. This milestone project, valued at $2.5 million, underscores the growing role of TES in advancing sustainable energy solutions.

Innovative TES Technology

The bGen™ system utilizes crushed rocks to store high-temperature heat, which can be harnessed to generate steam, hot air, or hot water on demand. This approach allows for the efficient use of excess renewable energy or off-peak electricity, and parallels microreactor storage advances that broaden thermal options, providing a reliable and cost-effective means of meeting heating needs. At SUNY Purchase College, the bGen™ system is designed to supply nearly 100% of the heating requirements for the Physical Education Building.

Environmental Impact

The implementation of the bGen™ system is expected to eliminate approximately 550 metric tons of greenhouse gas emissions annually. This reduction aligns with New York State's ambitious climate goals, including a 40% reduction in greenhouse gas emissions by 2030, even as transmission constraints can limit cross-border imports. The project also demonstrates the potential of TES to support the state's transition to a cleaner and more resilient energy system.

Collaborative Effort

The successful deployment of the bGen™ system at SUNY Purchase College is the result of a collaborative effort between Brenmiller Energy and NYPA. The project was partially funded by a grant from the Israel-U.S. Binational Industrial Research and Development (BIRD) Foundation. This partnership highlights the importance of international cooperation in advancing innovative energy technologies, as seen in OPG-TVA nuclear collaboration efforts across North America.

Future Prospects

The successful installation and operation of the bGen™ system at SUNY Purchase College serve as a model for broader adoption of TES technology in institutional settings, as OPG's SMR commitment signals parallel low-carbon investment across the region. Brenmiller Energy and NYPA plan to share the project's findings through a webinar hosted by the Renewable Thermal Collaborative on May 19, 2025. This initiative aims to promote the scalability and replicability of TES solutions across New York State and beyond.

As the demand for sustainable energy solutions continues to grow, the successful deployment of the bGen™ system at SUNY Purchase College marks a significant step forward in the integration of TES technology into the U.S. energy landscape, while projects like Pickering B refurbishment underscore parallel clean power investments. The project not only demonstrates the feasibility of TES but also sets a precedent for future initiatives aimed at reducing carbon emissions and enhancing energy efficiency.

Brenmiller Energy's commitment to innovation and sustainability positions the company as a key player in the evolving energy sector. With continued support from partners like NYPA and the BIRD Foundation, and as jurisdictions advance first SMR deployments in North America, Brenmiller Energy is poised to expand the reach of its TES solutions, contributing to a more sustainable and resilient energy future.

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Iran Bushehr Earthquake rattles southern province near the Bushehr nuclear power plant, USGS reports M5.1 at 38 km depth; seismic activity along major fault lines raises safety, damage, and monitoring concerns.

Key Points

A magnitude 5.1 quake near Bushehr nuclear plant at 38 km depth, with no damage reported, per USGS.

✅ USGS lists magnitude 5.1 at 38 km depth

✅ Near Bushehr nuclear power plant; built for stronger quakes

✅ Iran lies on major fault lines; quake risk is frequent

A magnitude 5 earthquake struck southern Iran early Friday near the Islamic Republic's only nuclear power plant. There were no immediate reports of damage or injuries as Iran continues combined-cycle conversions across its power sector.

The quake hit Iran's Bushehr province at 5:23 a.m., according to the U.S. Geological Survey. It put the magnitude at 5.1 and the depth of the earthquake at 38 kilometres (24 miles), in a province tied to efforts to transmit electricity to Europe in coming years.

Iranian state media did not immediately report on the quake. However, the Bushehr nuclear power plant was designed to withstand much stronger earthquakes, a notable consideration as Iraq plans nuclear power plants to address shortages.

A magnitude 5 earthquake can cause considerable damage, including power disruptions that have seen blackouts spark protests in some Iranian cities.

Iran sits on major fault lines and is prone to near-daily earthquakes, yet it remains a key player in regional power, with Iran-Iraq energy cooperation ongoing. In 2003, a 6.6-magnitude quake flattened the historic city of Bam, killing 26,000 people, and today Iran supplies 40% of Iraq's electricity through cross-border power deals. Bam is near the Bushehr nuclear plant, which wasn’t damaged at that time, while more recently Iran finalized deals to rehabilitate Iraq's power grid to improve resilience.

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