C&O president urges owning mines and generation

By Reuters


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Coal traders in India need to diversify into power generation and mining to succeed in an increasingly competitive business, Ahmed Buhari, founder president of Dubai-based traders Coal & Oil (C&O), said.

C&O, which is seeking mines to buy, aims to gain an edge over competitors by building a coal-fired power plant in Tamil Nadu in southern India, Buhari said.

Its associate company Coastal Energen earlier this month finalized $800 million of financing, mostly from the State Bank of India, to build a 1,200 MW coal-fired plant at Tuticorin.

The project is for a merchant power plant. These have no single sales contract for the term of the project debt and have to sell power as a commodity as well as via offtake agreements.

"This is the first power plant in India to get financing for a merchant plant model," Buhari told Reuters in an interview.

"Raising that level of financing for a merchant plant was not an easy thing to do in these times when credit is tough. But the banks were satisfied," he said.

"C&O will no longer be just a trader but an integrated and diverse energy supplier. That's our strategy. It's no longer enough to merely trade coal," Buhari said.

C&O, founded by Buhari in 1998, is one of the key players in coal supply to the subcontinent. The company sells over 6 million tonnes of imported coal a year and has supply agreements with major producers in Indonesia, South Africa and Australia. Privately-owned C&O's 2008 turnover was $500 million.

India's coal imports have grown rapidly from almost nothing five years ago to a projected 70 million tonnes in the next fiscal year. Imports will continue to rise fast over the next 10-15 years because domestic supply cannot meet demand.

A few large traders dominate imports but competition is intensifying.

"The game is now changing in India," he said. "The state electricity boards, independent power producers, the big listed consumers, are looking for solid, stable suppliers of coal. Diversifying into generation strengthens our company and draws upon our years of expertise in fuel supply," he said.

Risks facing coal suppliers and consumers are much higher now, he said.

Tuticorin was an obvious site for a coal-fired plant designed to use low-quality Indonesian coal, Buhari said.

"At C&O we're all from Tamil Nadu. We're sons of the soil."

The plant's proximity to Tuticorin port makes it easy to bring in coal from Indonesia. There is easy access to the grid and a good choice of available land, he said.

India's two major areas of power growth are the Western states such as Punjab, Rajasthan, Maharashtra and Gujarat and in the South, Tamil Nadu, Kerala, Karnataka and Andhra Pradesh.

Per capita power consumption in the south is low — below that of China, he said, but with great potential to grow.

"Tamil Nadu is also the automotive hub of India. It's the Detroit of the South. We have Hyundai, Ford, already there and many others are relocating to the south," he said.

The information technology industry, steel, textiles and others also see the advantages of relocating there. For example, Karnataka has large iron ore reserves, he said.

Industrial growth in the region requires more power. At least 30,000 MW of generation capacity needs to be added in South India over the next five years, he said.

Coastal Energen has offtake agreements already. Tata Power will take most of the power, 25 percent will go to the state government, some to neighboring states such as Kerala.

The plant can be expanded from 1,200 MW to 3,600-4,000 MW.

The company aims to sign "cap and collar" supply deals with Indonesian producers, he said. These set a minimum and maximum price, which offer some protection from price volatility.

Chinese boiler manufacturer Harbin Boiler Co Ltd will deliver the plant boilers within 22 months. Generation will start in three years.

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US Grid Gets an Overhaul for Renewables

FERC Transmission Planning Overhaul streamlines interregional grid buildouts, enabling high-voltage lines, renewable integration, and grid reliability to scale, cutting fossil reliance while boosting decarbonization, climate resilience, and affordability across regions facing demand and extreme weather.

 

Key Points

Federal rule updating interregional grid planning to integrate renewables, share costs, and improve reliability.

✅ Accelerates high-voltage, interregional lines for renewable transfer

✅ Optimizes transmission planning and cost allocation frameworks

✅ Boosts grid reliability, resilience, and emissions reductions

 

The US took a significant step towards a cleaner energy future on May 13th, 2024. The Federal Energy Regulatory Commission (FERC) approved the first major update to the country's electric transmission policy in over a decade, while congressional Democrats continue to push for action on aggregated DERs within FERC's remit today. This overhaul aims to streamline the process of building new power lines, specifically those that connect different regions. This improved connectivity is crucial for integrating more renewable energy sources like wind and solar into the national grid.

The current system faces challenges in handling the influx of renewables, and the aging U.S. grid amplifies those hurdles today. Renewable energy sources are variable by nature – the sun doesn't always shine, and the wind doesn't always blow. Traditionally, power grids have relied on constantly running power plants, like coal or natural gas, to meet electricity demands. These plants can be easily adjusted to produce more or less power as needed. However, renewable energy sources require a different approach.

The new FERC policy focuses on building more interregional transmission lines. These high-voltage power lines would allow electricity generated in regions with abundant solar or wind power, and even enable imports of green power from Canada in certain corridors, to be transmitted to areas with lower renewable energy resources. For example, solar energy produced in sunny states like California could be delivered to meet peak demand on the East Coast during hot summer days.

This improved connectivity offers several advantages. Firstly, it allows for a more efficient use of renewable resources. Secondly, it reduces the need for fossil fuel-based power plants, leading to cleaner air and lower greenhouse gas emissions. Finally, a more robust grid is better equipped to handle extreme weather events, which are becoming increasingly common due to climate change, and while Biden's climate law shows mixed results on decarbonization, stronger transmission supports resilience.

The need for an upgrade is undeniable. The Biden administration has set ambitious goals for decarbonizing the power sector by 2035, including proposals for a clean electricity standard as a pathway to those targets. A study by the US Department of Energy estimates that achieving this target will require more than doubling the country's regional transmission capacity and increasing interregional capacity by more than fivefold. The aging US grid is already struggling to keep up with current demands, and without significant improvements, it could face reliability issues in the future.

The FERC's decision has been met with praise from environmental groups and renewable energy companies. They see it as a critical step towards achieving a clean energy future. However, some stakeholders, including investor-owned utilities, have expressed concerns about the potential costs associated with building new transmission lines, citing persistent barriers to development identified in recent Senate testimony. Finding the right balance between efficiency, affordability, and environmental responsibility will be key to the success of this initiative.

The road ahead won't be easy. Building new power lines is a complex process that can face opposition from local communities, and broader disputes over electricity pricing changes often complicate planning and approvals. However, the potential benefits of a modernized grid are significant. By investing in this overhaul, the US is taking a crucial step towards a more reliable, sustainable, and cleaner energy future.

 

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City of Vancouver named Clean Energy Champion for Bloedel upgrades

BC Hydro Clean Energy Champions highlights Vancouver's Bloedel Conservatory electrification with a massive heat pump, clean electricity, LED lighting, deep energy efficiency, and 90% greenhouse gas reductions advancing climate action across buildings and industry.

 

Key Points

A BC Hydro program honoring clean electricity adoption in homes, transport, and industry to replace fossil fuels.

✅ Vancouver's Bloedel Conservatory cut GHGs by 90% with a heat pump

✅ LEDs and electrification boost efficiency, comfort, and reliability

✅ Nominations open for residents, businesses, and Indigenous groups

 

The City of Vancouver has been selected as BC Hydro’s first Clean Energy Champion for energy efficient upgrades made at the Bloedel Conservatory that cut greenhouse gas emissions by 90 per cent, a meaningful step given concerns about 2050 greenhouse gas targets in B.C.

BC Hydro’s Clean Energy Champions program is officially being launched today to recognize residents, businesses, municipalities, Indigenous and community groups across B.C. that have made the choice to switch from using fossil fuels to using clean electricity in three primary areas: homes and buildings, transportation, and industry, even as drought challenges power generation in B.C. The City of Vancouver is being recognized as the first champion for demonstrating its commitment to using clean energy, including power from projects like Site C's electricity, to fight climate change at its landmark Bloedel Conservatory.

Earlier this year, the City of Vancouver installed a large air source heat pump at Bloedel Conservatory – more than 50 times the size of a heat pump used in a typical B.C. home – that uses electricity instead of natural gas to heat and cool the dome's interior, which is home to more than 500 exotic plants and flowers, and 100 exotic birds, aligning with citywide debates such as Vancouver’s reversal on gas appliances policy. It is the biggest heat pump the City of Vancouver has ever installed, with 210 tonnes of cooling capacity.

A heat pump that provides cooling in the summer and heating in the winter, helping reduce reliance on wasteful air conditioning that can drive up energy bills, is ideal for the conservatory, as its dome is completely made of glass, which can be challenging for temperature regulation. While the dome experiences a lot of heat loss in the colder months, its need for cooling in warmer weather is even greater to ensure the safety of the wildlife and plants that call it home.

The clean energy upgrades do not end there though. All lighting in the building has been upgraded to energy-efficient LEDs, reflecting conservation themes highlighted by 2018 Earth Hour electricity use discussions, and outside colour-changing LEDs now surround the perimeter and light up the dome at night.

BC Hydro is calling for nominations from B.C. residents, businesses, municipalities or Indigenous and community groups that have taken steps to lower their carbon footprint and adopt new clean energy technologies, and continues to support customers through programs like its winter payment plan during colder months. If you or someone you know is a Clean Energy Champion, nominate them at bchydro.com/cleanenergychampions.

 

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Canada Faces Critical Crunch in Electrical Supply

Canada Electricity Supply Crunch underscores grid reliability risks, aging infrastructure, and rising demand, pushing upgrades in transmission, energy storage, smart grid technology, and renewable energy integration to protect industry, consumers, and climate goals.

 

Key Points

A nationwide power capacity shortfall stressing the grid, raising outage risks and slowing the renewable transition.

✅ Demand growth and aging infrastructure strain transmission capacity

✅ Smart grid, storage, and interties improve reliability and flexibility

✅ Accelerated renewables and efficiency reduce fossil fuel reliance

 

Canada, known for its vast natural resources and robust energy sector, is now confronting a significant challenge: a crunch in electrical supply. A recent report from EnergyNow.ca highlights the growing concerns over Canada’s electricity infrastructure, revealing that the country is facing a critical shortage that could impact both consumers and industries alike. This development raises pressing questions about the future of Canada’s energy landscape and its implications for the nation’s economy and environmental goals.

The Current Electrical Supply Dilemma

According to EnergyNow.ca, Canada’s electrical supply is under unprecedented strain due to several converging factors. One major issue is the rapid pace of economic and population growth, particularly in urban centers. This expansion has increased demand for electricity, putting additional pressure on an already strained grid. Compounding this issue are aging infrastructure and a lack of sufficient investment in modernizing the electrical grid to meet current and future needs, with interprovincial frictions such as the B.C. challenge to Alberta's export restrictions further complicating coordination.

The report also points out that Canada’s reliance on certain types of energy sources, including fossil fuels, exacerbates the problem. While the country has made strides in renewable energy, including developments in clean grids and batteries across provinces, the transition has not kept pace with the rising demand for electricity. This imbalance highlights a crucial gap in Canada’s energy strategy that needs urgent attention.

Economic and Social Implications

The shortage in electrical supply has significant economic and social implications. For businesses, particularly those in energy-intensive sectors such as manufacturing and technology, the risk of power outages or unreliable service can lead to operational disruptions and financial losses. Increased energy costs due to supply constraints could also affect profit margins and competitiveness on both domestic and international fronts, with electricity exports at risk amid trade tensions.

Consumers are not immune to the impact of this electrical supply crunch. The potential for rolling blackouts or increased energy prices, as debates over electricity rates and innovation continue nationwide, can strain household budgets and affect overall quality of life. Additionally, inconsistent power supply can affect essential services, including healthcare facilities and emergency services, highlighting the critical nature of reliable electricity for public safety and well-being.

Investment and Infrastructure Upgrades

Addressing the electrical supply crunch requires significant investment in infrastructure and technology, and recent tariff threats have boosted support for Canadian energy projects that could accelerate these efforts. The EnergyNow.ca report underscores the need for modernizing the electrical grid to enhance capacity and resilience. This includes upgrading transmission lines, improving energy storage solutions, and expanding the integration of renewable energy sources such as wind and solar power.

Investing in smart grid technology is also essential. Smart grids use digital communication and advanced analytics to optimize electricity distribution, detect outages, and manage demand more effectively. By adopting these technologies, Canada can better balance supply and demand, reduce the risk of blackouts, and improve overall efficiency in energy use.

Renewable Energy Transition

Transitioning to renewable energy sources is a critical component of addressing the electrical supply crunch. While Canada has made progress in this area, the pace of change needs to accelerate under the new Clean Electricity Regulations for 2050 that set long-term targets. Expanding the deployment of wind, solar, and hydroelectric power can help diversify the energy mix and reduce reliance on fossil fuels. Additionally, supporting innovations in energy storage and grid management will enhance the reliability and sustainability of renewable energy.

The EnergyNow.ca report highlights several ongoing initiatives and projects aimed at increasing renewable energy capacity. However, these efforts must be scaled up and supported by both public policy and private investment to ensure that Canada can meet its energy needs and climate goals.

Policy and Strategic Planning

Effective policy and strategic planning are crucial for addressing the electrical supply challenges, with an anticipated electricity market reshuffle in at least one province signaling change ahead. Government action is needed to support infrastructure investment, incentivize renewable energy adoption, and promote energy efficiency measures. Collaborative efforts between federal, provincial, and municipal governments, along with private sector stakeholders, will be key to developing a comprehensive strategy for managing Canada’s electrical supply.

Public awareness and engagement are also important. Educating consumers about energy conservation practices and encouraging the adoption of energy-efficient technologies can contribute to reducing overall demand and alleviating some of the pressure on the electrical grid.

Conclusion

Canada’s electrical supply crunch is a pressing issue that demands immediate and sustained action. The growing demand for electricity, coupled with aging infrastructure and a lagging transition to renewable energy, poses significant challenges for the country’s economy and daily life. Addressing this issue will require substantial investment in infrastructure, advancements in technology, and effective policy measures. By taking a proactive and collaborative approach, Canada can navigate this crisis and build a more resilient and sustainable energy future.

 

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Biggest offshore windfarm to start UK supply this week

Hornsea One Offshore Wind Farm delivers first power to the UK grid, scaling renewable energy with 1.2GW capacity, giant offshore turbines, and Yorkshire coast infrastructure to replace delayed nuclear and cut fossil fuel emissions.

 

Key Points

Hornsea One Offshore Wind Farm is a 1.2GW UK project delivering offshore renewable power to about 1 million homes.

✅ 174 turbines over 407 km2; Siemens Gamesa supply chain in the UK

✅ 1.2GW capacity can power ~1m homes; phases scale with 10MW+ turbines

✅ Supports UK grid, replaces delayed nuclear, cuts fossil generation

 

An offshore windfarm on the Yorkshire coast that will dwarf the world’s largest when completed is to supply its first power to the UK electricity grid this week, mirroring advances in tidal electricity projects delivering to the grid as well.

The Danish developer Ørsted, which has installed the first of 174 turbines at Hornsea One, said it was ready to step up its plans and fill the gap left by failed nuclear power schemes.

The size of the project takes the burgeoning offshore wind power sector to a new scale, on a par with conventional fossil fuel-fired power stations.

Hornsea One will cover 407 square kilometres, five times the size of the nearby city of Hull. At 1.2GW of capacity it will power 1m homes, making it about twice as powerful as today’s biggest offshore windfarm once it is completed in the second half of this year.

“The ability to generate clean electricity offshore at this scale is a globally significant milestone at a time when urgent action needs to be taken to tackle climate change,” said Matthew Wright, UK managing director of Ørsted, the world’s biggest offshore windfarm builder.

The power station is only the first of four planned in the area, with a green light and subsidies already awarded to a second stage due for completion in the early 2020s, and interest from Japanese utilities underscoring growing investor appetite.

The first two phases will use 7MW turbines, which are taller than London’s Gherkin building.

But the latter stages of the Hornsea development could use even more powerful, 10MW-plus turbines. Bigger turbines will capture more of the energy from the wind and should lower costs by reducing the number of foundations and amount of cabling firms need to put into the water, with developers noting that offshore wind can compete with gas in the U.S. as costs fall.

Henrik Poulsen, Ørsted’s chief executive, said he was in close dialogue with major manufacturers to use the new generation of turbines, some of which are expected to approach the height of the Shard in London, the tallest building in the EU.

The UK has a great wind resource and shallow enough seabed to exploit it, and could even “power most of Europe if it [the UK] went to the extreme with offshore”, he said.

Offshore windfarms could help ministers fill the low carbon power gap created by Hitachi and Toshiba scrapping nuclear plants, the executive suggested. “If nuclear should play less of a role than expected, I believe offshore wind can step up,” he said.

New nuclear projects in Europe had been “dramatically delayed and over budget”, he added, in comparison to “the strong track record for delivering offshore [wind]”.

The UK and Germany installed 85% of new offshore wind power capacity in the EU last year, according to industry data, with wind leading power across several markets. The average power rating of the turbines is getting bigger too, up 15% in 2018.

The turbines for Hornsea One are built and shipped from Siemens Gamesa’s factory in Hull, part of a web of UK-based suppliers that has sprung up around the growing sector, such as Prysmian UK's land cables supporting grid connections.

Around half of the project’s transition pieces, the yellow part of the structure that connects the foundation to the tower, are made in Teeside. Many of the towers themselves are made by a firm in Campbeltown in the Scottish highlands. Altogether, about half of the components for the project are made in the UK.

Ørsted is not yet ready to bid for a share of a £60m pot of further offshore windfarm subsidies, to be auctioned by the government this summer, but expects the price to reach even more competitive levels than those seen in 2017.

Like other international energy companies, Ørsted has put in place contingency planning in event of a no-deal Brexit – but the hope is that will not come to pass. “We want a Brexit deal that will facilitate an orderly transition out of the union,” said Poulsen.

 

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USAID Delivers Mobile Gas Turbine Power Plant to Ukraine

USAID GE Mobile Power Plant Ukraine supplies 28MW of emergency power and distributed generation to bolster energy security, grid resilience, and critical infrastructure reliability across cities and regions amid ongoing attacks.

 

Key Points

A 28MW GE gas turbine from USAID providing mobile, distributed power to strengthen Ukraine's grid resilience.

✅ 28MW GE gas turbine; power for 100,000 homes

✅ Mobile deployment to cities and regions as needed

✅ Supports hospitals, schools, and critical infrastructure

 

Deputy U.S. Administrator Isobel Coleman announced during her visit to Kyiv that the U.S. Agency for International Development (USAID) has provided the Government of Ukraine with a mobile gas turbine power plant purchased from General Electric (GE), as discussions of a possible agreement on power plant attacks continue among stakeholders.

The mobile power plant was manufactured in the United States by GE’s Gas Power business and has a total output capacity of approximately 28MW, which is enough to provide the equivalent electricity to at least 100,000 homes. This will help Ukraine increase the supply of electricity to homes, hospitals, schools, critical infrastructure providers, and other institutions, as the country has even resumed electricity exports in recent months. The mobile power plant can be operated in different cities or regions depending on need, strengthening Ukraine’s energy security amid the Russian Federation’s continuing strikes against critical infrastructure.   

Since the February 2022 full-scale invasion of Ukraine, and particularly since October 2022, the Russian Federation has deliberately targeted critical civilian heating, power, and gas infrastructure in an effort to weaponize the winter, raising nuclear risks to grid stability noted by international monitors. Ukraine has demonstrated tremendous resilience in the wake of these attacks, with utility workers routinely risking their lives to repair the damage, often within hours of air strikes, even as Russia builds power lines to reactivate the Zaporizhzhia plant to influence the energy situation.

The collaboration between USAID and GE reflects the U.S. government’s emphasis on engaging American private sector expertise and procuring proven and reliable equipment to meet Ukraine’s needs. Since the start of Putin’s full-scale war against Ukraine, USAID has both directly procured equipment for Ukraine from American companies and engaged the private sector in partnerships to meet Ukraine’s urgent wartime needs, with U.S. policy debates such as a proposal on Ukraine’s nuclear plants drawing scrutiny.

This mobile power plant is the latest example of USAID assistance to Ukraine’s energy sector since the start of the Russian Federation’s full-scale invasion, during which Ukraine has resumed electricity exports as conditions improved. USAID has already delivered more than 1,700 generators to 22 oblasts across Ukraine, with many more on the way. These generators ensure electricity and heating for schools, hospitals, accommodation centers for internally-displaced persons, district heating companies, and water systems if and when power is knocked out by the Russian Federation’s relentless, systematic and cruel attacks against critical civil infrastructure. USAID has invested $55 million in Ukraine’s heating infrastructure to help the Ukrainian people get through winter. This support will benefit up to seven million Ukrainians by supporting repairs and maintenance of pipes and other equipment necessary to deliver heating to homes, hospitals, schools, and businesses across Ukraine. USAID’s assistance builds on over two decades of support to Ukraine to strengthen the country’s energy security, complementing growth in wind power that is harder to destroy.

 

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The Haves and Have-Nots of Electricity in California

California Public Safety Power Shutoffs highlight wildfire prevention as PG&E outages disrupt schools, businesses, and rural communities, driving generator use, economic hardship, and emergency preparedness across Northern California during high-wind events.

 

Key Points

Utility outages to reduce wildfire risk during extreme winds, impacting homes and businesses in high-risk California.

✅ PG&E cuts power during high winds to prevent wildfires

✅ Costs rise for generators, fuel, batteries, and spoiled food

✅ Rural, low-income communities face greater economic losses

 

The intentional blackout by California’s largest utility this week put Forest Jones out of work and his son out of school. On Friday morning Mr. Jones, a handyman and single father, sat in his apartment above a tattoo parlor waiting for the power to come back on and for school to reopen.

“I’ll probably lose $400 or $500 dollars because of this,” said Mr. Jones, who lives in the town of Paradise, which was razed by fire last year and is slowly rebuilding. “Things have been really tough up here.”

Millions of people were affected by the blackout, which spanned the outskirts of Silicon Valley to the forests of Humboldt County near the Oregon border. But the outage, which the power company said was necessary to reduce wildfire risk across the region, also drew a line between those who were merely inconvenienced and those who faced a major financial hardship.

To have the lights on, the television running and kitchen appliances humming is often taken for granted in America, even as U.S. grid during coronavirus questions persisted. During California’s blackout it became an economic privilege.

The economic impacts of the shut-off were especially acute in rural, northern towns like Paradise, where incomes are a fraction of those in the San Francisco Bay Area.

Both wealthy and poorer areas were affected by the blackout but interviews across the state suggested that being forced off the grid disproportionately hurt the less affluent. One family in Humboldt County said they had spent $150 on batteries and water alone during the shutdown.

“To be prepared costs money,” Sue Warhaftig, a massage therapist who lives in Mill Valley, a wealthy suburb across the Golden Gate Bridge from San Francisco. Ms. Warhaftig spent around two days without electricity but said she had been spared from significant sacrifices during the blackout.

She invested in a generator to keep the refrigerator running and to provide some light. She cooked in the family’s Volkswagen camper van in her driveway. At night she watched Netflix on her phone, which she was able to charge with the generator. Her husband, a businessman, is in London on a work trip. Her two sons, both grown, live in Southern California and Seattle.

“We were inconvenienced but life wasn’t interrupted,” Ms. Warhaftig said. “But so many people’s lives were.

Pacific Gas & Electric restored power to large sections of Northern California on Friday, including Paradise, where the electricity came back on in the afternoon. But hundreds of thousands of people in other areas remained in the dark. The carcasses of burned cars still littered the landscape around Paradise, where 86 people died in the Camp Fire last year, some of them while trying to escape.

Officials at power company said that by Saturday they hoped to have restored power to 98 percent of the customers who were affected.

The same dangerous winds that spurred the shut-off in Northern California have put firefighters to work in the south. The authorities in Los Angeles County ordered the evacuation of nearly 100,000 people on Friday as the Saddleridge Fire burned nearly 5,000 acres and destroyed 25 structures. The Sandalwood Fire, which ignited Thursday in Riverside County, had spread to more than 800 acres and destroyed 74 structures by Friday afternoon.

While this week’s outage was the first time many customers in Northern California experienced a deliberate power shut-off, residents in and around Paradise have had their power cut four times in recent months, residents say.

Many use a generator, but running one has become increasingly expensive with gasoline now at more than $4 a gallon in California.

On Friday, Dennis and Viola Timmer drove up the hill to their home in Magalia, a town adjacent to Paradise, loaded with $102 dollars of gasoline for their generators. It was their second gasoline run since the power went out Tuesday night.

The couple, retired and on a fixed income after Mr. Timmer’s time in the Navy and in construction, said the power outage had severely limited their ability to do essential tasks like cooking, or to leave the house.

“You know what it feels like? You’re in jail,” said Ms. Timmer, 72. “You can’t go anywhere with the generators running.”

Since the generators are not powerful enough to run heat or air conditioning, the couple slept in their den with an electric space heater.

“It’s really difficult because you don’t have a normal life,” Ms. Timmer said. “You’re trying to survive.”

To be sure, the shutdown has affected many people regardless of economic status, and similar disruptions abroad, like a London power outage that disrupted routines, show how widespread such challenges can be. The areas without power were as diverse as the wealthy suburbs of Silicon Valley, the old Gold Rush towns of the Sierra Nevada, the East Bay of San Francisco and the seaside city of Arcata.

Ms. Cahn’s cellphone ran out of power during the blackout and even when she managed to recharge it in her car cell service was spotty, as it was in many areas hit by the blackout.

Accustomed to staying warm at night with an electric blanket, Ms. Cahn slept under a stack of four blankets.

“I’m doing what I have to do which is not doing very much,” she said.

Further south in Marin City, Chanay Jackson stood surrounded by fumes from generators still powering parts of the city.

She said that food stamps were issued on the first of the month and that many residents who had to throw away food were out of luck.

“They’re not going to issue more food stamps just because the power went out,” Ms. Jackson said. “So they’re just screwed until next month.”

Strong winds have many times in the past caused power lines to come in contact with vegetation, igniting fires that are then propelled by the gusts, and hurricanes elsewhere have crippled infrastructure with Louisiana grid rebuild after Laura according to state officials. This was the case with the Camp Fire.

Since higher elevations had more extreme winds many of the neighborhoods where power was turned off this week were in hills and canyons, including in the Sierra Nevada.

The shut-off, which by one estimate affected a total of 2.5 million people, has come under strong criticism by residents and politicians, and warnings from Cal ISO about rolling blackouts as the power grid strained. The company’s website crashed just as customers sought information about the outage. Gov. Gavin Newsom called it unacceptable. But his comments were nuanced, criticizing the way the shut-off was handled, not the rationale for it. Mr. Newsom and others said the ravages of the Camp Fire demanded preventive action to prevent a reoccurrence.

Yet the calculus of trying to avoid deadly fires by shutting off power will continue to be debated as California enters its peak wildfire season, even as electricity reliability during COVID-19 was generally maintained for most consumers.

In the city of Grass Valley, Matthew Gottschalk said he and his wife realized that a generator was essential when they calculated that they had around $500 worth of food in their fridge.

“I don’t know what we would have done,” said Mr. Gottschalk, whose power went out Tuesday night.

His neighbors are filling coolers with ice. Everyone is hoping the power will come back on soon.

“Ice is going to run out and gas is going to run out,” he said.

 

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