Pakistan to add more than 5,000 MW by June 2010

California Income-Based Utility Fees would overhaul electricity bills as CPUC weighs fixed charges tied to income, grid maintenance costs, AB 205 changes, and per-kilowatt-hour rates, shifting from pure usage pricing to hybrid utility rate design.

Key Points

Income-based utility fees are fixed monthly charges tied to earnings, alongside per-kWh rates, to help fund grid costs.

✅ CPUC considers fixed charges by income under AB 205

✅ Separates grid costs from per-kWh energy charges

✅ Could shift rooftop solar and EV charging economics

Electricity bills in California are likely to change dramatically in 2026, with major changes under discussion statewide.

The California Public Utilities Commission (CPUC) is in the midst of an unprecedented overhaul of the way most of the state’s residents pay for electricity, as it considers revamping electricity rates to meet grid and climate goals.

Utility bills currently rely on a use-more pay-more system, where bills are directly tied to how much electricity a resident consumes, a setup that helps explain why prices are soaring for many households.

California lawmakers are asking regulators to take a different approach, and some are preparing to crack down on utility spending as oversight intensifies. Some of the bill will pay for the kilowatt hours a customer uses and a monthly fixed fee will help pay for expenses to maintain the electric grid: the poles, the substations, the batteries, and the wires that bring power to people’s homes.

The adjustments to the state’s public utility code, section 739.9, came about because of changes written into a sweeping energy bill passed last summer, AB 205, though some lawmakers now aim to overturn income-based charges in subsequent measures.

A stroke of a pen, a legislative vote, and the governor’s signature created a move toward unprecedented income-based fixed charges across the state.

“This was put in at the last minute,” said Ahmad Faruqui, a California economist with a long professional background in utility rates. “Nobody even knew it was happening. It was not debated on the floor of the assembly where it was supposedly passed. Of course, the governor signed it.”

Faruqui wonders who was responsible for legislation that was added to the energy bill during the budget writing process. That process is not transparent.

“It’s a very small clause in a very long bill, which is mostly about other issues,” Faruqui said.

But that small adjustment could have a massive impact on California residents, because it links the size of a monthly flat fee for utility service to a resident’s income. Earn more money and pay a higher flat fee.

That fee must be paid even before customers are charged for how much power they draw.

Regulators interpreted legislative change as a mandate, but Faruqui is not sold.

“They said the commission may consider or should consider,” Faruqui said. “They didn’t mandate it. It’s worth re-reading it.”

In fact, the legislative language says the commission “may” adopt income-based flat fees for utilities. It does not say the commission “should” adopt them.

Nevertheless, the CPUC has already requested and received nine proposals for how a flat fee should be implemented, as regulators face calls for action amid soaring electricity bills.

The suggestions came from consumer groups, environmentalists, the solar industry and utilities.

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Canada 2035 Gasoline Car Ban accelerates EV adoption, zero-emission transport, and climate action, with charging infrastructure, rebates, and industry investment supporting net-zero goals while addressing affordability, range anxiety, and consumer acceptance nationwide.

Key Points

A federal policy to end new gas car sales by 2035, boosting EV adoption, emissions goals, and charging infrastructure.

✅ Ends new gas car and light-truck sales by 2035

✅ Expands charging infrastructure and grid readiness

✅ Incentives, rebates, and industry investment drive adoption

Canada has set its sights on a bold and transformative goal: to ban the sale of new gasoline-powered passenger cars and light-duty trucks by the year 2035. This ambitious target, announced by the federal government, underscores Canada's commitment to combating climate change and accelerating the adoption of electric vehicles (EVs) nationwide, supported by forthcoming EV sales regulations from Ottawa.

The Federal Initiative

Under the leadership of Prime Minister Justin Trudeau, Canada aims to significantly reduce greenhouse gas emissions from the transportation sector, which accounts for a substantial portion of the country's carbon footprint. The initiative aligns with Canada's broader climate objectives, including achieving net-zero emissions by 2050.

Driving Forces Behind the Decision

The decision to phase out internal combustion engine vehicles reflects growing recognition of the urgency to transition towards cleaner transportation alternatives, even as 2019 electricity from fossil fuels still powered a notable share of Canada's grid. Minister of Environment and Climate Change Jonathan Wilkinson emphasizes the environmental benefits of electric vehicles, citing their potential to lower emissions and improve air quality in urban centers across the country.

Challenges and Opportunities

While the move towards electric vehicles presents promising opportunities for reducing emissions, it also poses challenges. Key considerations include infrastructure development, affordability, and consumer acceptance of EV technology, amid EV shortages and wait times that can influence buying decisions. Addressing these hurdles will require coordinated efforts from government, industry stakeholders, and consumers alike.

Industry Response

The automotive industry plays a crucial role in realizing Canada's EV ambitions. Automakers are increasingly investing in electric vehicle production and innovation to meet evolving consumer demand and regulatory requirements, including cross-border Canada-U.S. collaboration on supply chains. The transition offers opportunities for job creation, technological advancement, and economic growth in the clean energy sector.

Provincial Perspectives

Provinces across Canada are pivotal in facilitating the transition to electric vehicles. Some provinces have already implemented incentives such as rebates for EV purchases, charging infrastructure investments, and policy frameworks to support emissions reduction targets, even as Quebec's EV dominance push faces scrutiny from experts. Collaborative efforts between federal and provincial governments are essential in ensuring a cohesive approach to achieving national EV goals.

Consumer Considerations

For consumers, the shift towards electric vehicles represents a paradigm shift in transportation choices. Factors such as range anxiety, charging infrastructure availability, and upfront costs, with one EV cost survey citing price as the main barrier, remain considerations for prospective buyers. Government incentives and subsidies aim to alleviate some of these concerns and promote widespread EV adoption.

Looking Ahead

As Canada navigates towards a future without gasoline-powered vehicles, stakeholders must work together to overcome challenges and capitalize on opportunities presented by the electric vehicle revolution, even as critics of the 2035 mandate question its feasibility. Continued investments in infrastructure, innovation, and consumer education will be critical in paving the way for a sustainable and prosperous automotive industry.

Conclusion

Canada's commitment to phasing out gasoline-powered vehicles by 2035 marks a pivotal moment in the country's climate action agenda. By embracing electric vehicles, Canada aims to lead by example in combatting climate change, fostering innovation, and building a greener future for generations to come. The success of this ambitious initiative hinges on collective efforts to transform the automotive landscape and accelerate towards a sustainable transportation future.

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NB Power copper thefts highlight risks at high-voltage substations, with vandalism, fatalities, infrastructure damage, ratepayer costs, and law enforcement alerts tied to metal prices, stolen electricity, and safety concerns across New Brunswick and Nova Scotia.

Key Points

Substation metal thefts causing fatalities, outages, safety risks, and higher costs that impact NB ratepayers.

✅ Spike aligns with copper price near $3 per pound

✅ Fatal break-ins at high-voltage facilities in Bathurst

✅ Repairs, delays, and safety risks for crews, customers

New Brunswick's power utility is urging people to stay away from its substations, saying the valuable copper they contain is proving hard to resist for thieves.

NB Power has seen almost as many incidents of theft and vandalism to its property in April and May of this year, than in all of last year.

In the 2018-2019 fiscal year, the utility recorded 16 cases of theft and/or vandalism.

In April and May, there have already been 13 cases.

One of those was a fatal incident in Bathurst. On April 13, a 41-year-old man was found unresponsive and later died, after breaking into a substation. It was the second fatality linked to a break-in at an NB Power facility in 10 years.

The investigation is still ongoing, but NB Power believes the man was trying to steal copper.

The power utility has been ramping up its efforts -- finding alternate ways to secure its properties, and educate the public -- on the dangers of copper theft, as utilities work to adapt to climate change that can exacerbate severe weather.

“We really, really, really want to stress that if you’re hitting the wrong wire, cutting the wrong wire, breaking in to or cutting fences, a lot of very bad things can happen,” said NB Power spokesperson Marc Belliveau.

In the 2017-2018 fiscal year, there were 24 recorded cases of theft and/or vandalism.

It also comes at a financial cost for NB Power, and ratepayers -- on average, $330,000 a year. About two-thirds of that is copper. The rest is vehicle break-ins or stolen electricity.

“We’ve done analysis,” Belliveau said. “Often the number of break-ins correspond with the price spiking in copper. So, right now, copper’s about $3 a pound. If it was half of that, there might be half as many incidents.”

New Brunswick Public Safety Minister Carl Urquhart says he knows the utility and police are working to dissuade people from the dangers of the theft, and notes that debates around Site C dam stability issues reflect broader infrastructure safety concerns.

“We all know of incident after incident of major injuries and death caused by, simply by, copper,” he said.

Last November, a Dawson Settlement substation was targeted during a major, storm-related power outage in the province.

It meant NB Power had to divert crews to fix and secure the substation, delaying restoration times for some residents and underscoring efforts to improve local reliability across the grid.

Belliveau says that’s “most frustrating.”

“We’re really trying to take a more proactive approach. And certainly, we encourage people that if you know somebody who’s thinking of doing something like that, to really try and talk them out of it because it’s unbelievably dangerous to break in to a substation,” he said.

Nova Scotia Power, connected through the Maritime Link, was not able to provide details on thefts at their substations, but spokesman David Rodenhiser said "the value of the stolen copper is minor in comparison to the risk that’s created when thieves break into our high-voltage electrical substations."

It's not just risky for the people breaking in, and public opposition to projects like Site C underscores broader community safety concerns.

"It also puts the safety of the workers who maintain our substations at risk, because when thieves steal copper, the protective safety devices in the substations don’t work properly," Rodenhiser said.

Additionally, in Nova Scotia, projects like the Maritime Link have advanced regional transmission, and Nova Scotia Power’s copper components have identifying markers, which make that copper difficult to fence. Anyone who buys or sells stolen propery is at risk of criminal charges.

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Meaford Pumped Storage Project aims to balance the grid with hydro-electric generation, a hilltop reservoir, and transmission lines near Georgian Bay, pending environmental assessment, permitting, and federal review of impacts on fish and drinking water.

Key Points

TC Energy proposal to pump water uphill off-peak and generate 1,000 MW at peak, pending studies and approvals.

✅ Balances grid by storing off-peak energy and generating at peak.

✅ Requires reservoir, break wall, transmission lines, generating station.

✅ Environmental studies and federal review underway before approvals.

Plans for a $3.3 billion hydro-electric project in Meaford are still in the early study stages, but some residents have concerns about what it might mean for the environment, as past Site C stability issues have illustrated for large hydro projects.

A one-year permit was granted for TC Energy Corporation (TC Energy) to begin studies on the proposed location back in May, and cross-border projects like the New England Clean Power Link require federal permits as well to proceed. Local municipalities were informed of the project in June.

TC Energy is proposing to have a pumped storage project at the 4th Canadian Division Training (4CDTC) Meaford property, which is on federal lands.

A letter sent to local municipalities explains that the plan is to balance supply and demand on the electrical grid by pumping water uphill during off-peak hours. It would then release the water back into Georgian Bay during peak periods, generating up to 1,000 megawatts of electricity.

The project is expected to create 800 jobs over four years of construction, in addition to long-term operational positions.

According to the company's website, the proposed pump station would require a large reservoir on the military base, a generating station, transmission lines infrastructure, and a break wall 850 metres from shore.

Some residents fear the project will threaten the bay and the fish, echoing Site C dam concerns shared with northerners, and the region's drinking water.

Meaford's mayor says the town has no jurisdiction on federal lands, but that a list of concerns has been forwarded to the company, while Ontario First Nations have urged government action on urgent transmission needs elsewhere.

TC Energy will tackle preliminary engineering and environmental studies to determine the feasibility of the proposed location, which could take up to two years.

Once the assessments are done, they need to be presented to the government for further review and approval, as seen when Ottawa's Site C stance left work paused pending a treaty rights challenge.

TC Energy's website states that the company anticipates construction to begin in 2022 if it gets all the go-ahead, with the plant to begin operations four years later.

Input from residents is being collected until April 2020, similar to when the National Energy Board heard oral traditional evidence on the Manitoba-Minnesota transmission line.

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Geothermal Emergency Permitting accelerates BLM approvals on public lands via categorical exclusions for exploratory drilling and geophysical surveys, boosting domestic energy security, cutting timelines by up to a year, and streamlining low-impact reviews.

Key Points

A policy fast-tracking geothermal exploration on public lands, using BLM categorical exclusions to cut review delays.

✅ Categorical exclusions speed exploratory drilling approvals

✅ Cuts permitting timelines by up to one year

✅ Focused on public lands to enhance energy security

In a significant policy shift, the U.S. Department of the Interior has introduced emergency permitting procedures aimed at expediting the development of geothermal energy projects. This initiative, announced on May 30, 2025, is part of a broader strategy to enhance domestic energy production, seen in proposals to replace Obama's power plant overhaul and reduce reliance on foreign energy sources.

Background and Rationale

The decision to fast-track geothermal energy projects comes in the wake of President Donald Trump's declaration of a national energy emergency, which faces a legal challenge from Washington's attorney general, on January 20, 2025. This declaration cited high energy costs and an unreliable energy grid as threats to national security and economic prosperity. While the emergency order includes traditional energy resources such as oil, gas, coal, and uranium and nuclear energy resources, it notably excludes renewable sources like solar, wind, and hydrogen from its scope.

Geothermal energy, which harnesses heat from beneath the Earth's surface to generate electricity, is considered a reliable and low-emission energy source. However, its development has been hindered by lengthy permitting processes and environmental reviews, with recent NEPA rule changes influencing timelines. The new emergency permitting procedures aim to address these challenges by streamlining the approval process for geothermal projects.

Key Features of the Emergency Permitting Procedures

Under the new guidelines, the Bureau of Land Management (BLM) has adopted categorical exclusions to expedite the review and approval of geothermal energy exploration on public lands. These exclusions allow for faster permitting of low-impact activities, such as drilling exploratory wells and conducting geophysical surveys, without the need for extensive environmental assessments.

Additionally, the BLM has proposed a new categorical exclusion that would apply to operations related to the search for indirect evidence of geothermal resources. This proposal is currently open for public comment and, if finalized, would further accelerate the discovery of new geothermal resources on public lands.

Expected Impact on Geothermal Energy Development

The implementation of these emergency permitting procedures is expected to significantly reduce the time and cost associated with developing geothermal energy projects. According to the Department of the Interior, the new measures could cut permitting timelines by up to a year for certain types of geothermal exploration activities.

This acceleration in project development is particularly important given the untapped geothermal potential in regions like Nevada, which is home to some of the largest undeveloped geothermal resources in the country.

Industry and Environmental Reactions

The geothermal industry has largely welcomed the new permitting procedures, viewing them as a necessary step to unlock the full potential of geothermal energy. Industry advocates argue that reducing permitting delays will facilitate the deployment of geothermal projects, contributing to a more reliable and sustainable energy grid amid debates over electricity pricing changes that affect market signals.

However, the exclusion of solar and wind energy projects from the emergency permitting procedures has drawn criticism from some environmental groups. Critics argue that a comprehensive approach to energy development should include all renewable sources, not just geothermal, to effectively address climate change, as reflected in new EPA pollution limits for coal and gas power plants, and promote energy sustainability.

The U.S. government's move to implement emergency permitting procedures for geothermal energy development marks a significant step toward enhancing domestic energy production and reducing reliance on foreign energy sources. By streamlining the approval process for geothermal projects, the administration aims to accelerate the deployment of this reliable and low-emission energy source. While the exclusion of other renewable energy sources from the emergency procedures has sparked debate, especially after states like California halted an energy rebate program during a federal freeze, the focus on geothermal energy underscores its potential role in the nation's energy future.

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OPG-TVA SMR Partnership advances advanced nuclear technology and small modular reactors for 24/7 carbon-free baseload power, enabling net-zero goals, cross-border licensing, and deployment within a North American clean energy hub.

Key Points

A cross-border effort by OPG and TVA to develop, license, and deploy SMRs for reliable, carbon-free baseload power.

✅ Coordinates design, licensing, construction, and operations

✅ Supports 24/7 baseload, net-zero targets, and energy security

✅ Leverages Darlington and Clinch River early site permits

Two of North America's leading nuclear utilities unveiled a pioneering partnership to develop advanced nuclear technology as an integral part of a clean energy future and creating a North American energy hub. Ontario Power Generation, whose OPG's SMR commitment is well established, and the Tennessee Valley Authority will jointly work to help develop small modular reactors as an effective long-term source of 24/7 carbon-free energy in both Canada and the U.S.

The agreement allows the companies to coordinate their explorations into the design, licensing, construction and operation of small modular reactors.

"As leaders in our industry and nations, OPG and TVA share a common goal to decarbonize energy generation while maintaining reliability and low-cost service, which our customers expect and deserve," said Jeff Lyash, TVA President and CEO. "Advanced nuclear technology will not only help us meet our net-zero carbon targets but will also advance North American energy security."

"Nuclear energy has long been key to Ontario's clean electricity grid, and is a crucial part of our net-zero future," said Ken Hartwick, OPG President and CEO. "Working together, OPG and TVA will find efficiencies and share best practices for the long-term supply of the economical, carbon-free, reliable electricity our jurisdictions need, supported by ongoing Pickering life extensions across Ontario's fleet."

OPG and TVA have similar histories and missions. Both are based on public power models that developed from renewable hydroelectric generation before adding nuclear to their generation mixes. Today, nuclear generation accounts for significant portions of their carbon-free energy portfolios, with Ontario advancing the Pickering B refurbishment to sustain capacity.

Both are also actively exploring SMR technologies. OPG is moving forward with plans to deploy an SMR at its Darlington nuclear facility in Clarington, ON, as part of broader Darlington SMR plans now underway. The Darlington site is the only location in Canada licensed for new nuclear with a completed and accepted Environmental Assessment. TVA currently holds the only Nuclear Regulatory Commission Early Site Permit in the U.S. for small modular reactor deployment at its Clinch River site near Oak Ridge, TN.

No exchange of funding is involved. However, the collaboration agreement will help OPG and TVA reduce the financial risk that comes from development of innovative technology, as well as future deployment costs.

"TVA has the most recent experience completing a new nuclear plant in North America at Watts Bar and that knowledge is invaluable to us as we work toward the first SMR groundbreaking at Darlington," said Hartwick. "Likewise, because we are a little further along in our construction timing, TVA will gain the advantage of our experience before they start work at Clinch River."

"It's a win-win agreement that benefits all of those served by both OPG and TVA, as well as our nations," said Lyash. "Moving this technology forward is not only a significant step in advancing a clean energy future and Canada's climate goals, but also in creating a North American energy hub."

"With the demand for clean electricity on the rise around the world, Ontario's momentum is growing. The world is watching Ontario as we advance our work to fully unleash our nuclear advantage, alongside a premiers' SMR initiative that underscores provincial collaboration. I congratulate OPG and TVA – two great industry leaders – for working together to deploy SMRs and showcase and apply Canada's nuclear expertise that will deliver economic, health and environmental benefits for all of us to enjoy," said Todd Smith, Ontario Minister of Energy.

"The changing climate is a global crisis that requires global solutions. The partnership between the Tennessee Valley Authority and Ontario Power Generation to develop and deploy advanced nuclear technology is exactly the kind of innovative collaboration that is needed to quickly bring the next generation of nuclear carbon-free generation to market. I applaud the leadership that both companies are demonstrating to further strengthen our cross-border relationships," said Maria Korsnick, President and CEO, Nuclear Energy Institute.

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