Most Afghans still without power

By Associated Press


Electrical Testing & Commissioning of Power Systems

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The goal is to transform Afghanistan into a modern nation, fueled by a U.S.-led effort pouring $60 billion into bringing electricity, clean water, jobs, roads and education to this crippled country.

But the results so far — or lack of them — threaten to do more harm than good.

The reconstruction efforts have stalled and stumbled at many turns since the U.S. military arrived in 2001, undermining President Barack Obama's vow to deliver a safer, stable Afghanistan capable of stamping out the insurgency and keeping al-Qaida from re-establishing its bases here.

Poppy fields thrive, with each harvest of illegal opium fattening the bankrolls of terrorists and drug barons. Passable roads remain scarce and unprotected, isolating millions of Afghans who remain cut off from jobs and education. Electricity flows to only a fraction of the country's 29 million people.

Case in point: a $100 million diesel-fueled power plant that was supposed to be built swiftly to deliver electricity to more than 500,000 residents of Kabul, the country's largest city. The plant's costs tripled to $305 million as construction lagged a year behind schedule, and now it often sits idle because the Afghans were able to import cheaper power from a neighboring country before the plant came online.

What went wrong?

The failures of the power plant project are, in many ways, the failures of often ill-conceived efforts to modernize Afghanistan:

The Afghans fell back into bad habits that favored short-term, political decisions over wiser, long-term solutions. The U.S. wasted money and might by deferring to the looming deadline and seeming desirability of Afghan President Hamid Karzai's re-election efforts. And a U.S. contractor benefited from a development program that essentially gives vendors a blank check, allowing them to reap millions of dollars in additional profits with no consequences for mistakes.

Rebuilding Afghanistan is an international effort, but the U.S. alone has committed $51 billion to the project since 2001, and plans to raise the stakes to $71 billion over the next year — more than it has spent on reconstruction in Iraq since 2003.

Roughly half the money is going to bolster the Afghan army and police, with the rest earmarked for shoring up the country's crumbling infrastructure and inadequate social services.

There have been reconstruction successes, such as rebuilding a national highway loop left crumbling after decades of war, constructing or improving thousands of schools, and creating a network of health clinics.

But the number of Afghans with access to electricity has only inched up from 6 percent in 2001 to an estimated 10 percent now, well short of the development goal to provide power to 65 percent of urban and 25 percent of rural households by the end of this year.

Too many major projects are not delivering what was promised to the people, and rapidly dumping billions of reconstruction dollars into such an impoverished country is in some ways making matters worse, not better, Afghan Finance Minister Omar Zakhilwal says.

The U.S and its partners have wasted billions of dollars and spent billions more without consulting Afghan officials, Zakhilwal says.

All of that has ramped up corruption, undermined efforts to build a viable Afghan government, stripped communities of self-reliance by handing out cash instead of real jobs, and delivered projects like the diesel plant that the country can't afford, he says.

"The indicator of success in Afghanistan has been the wrong indicator... it has been spending," Zakhilwal says. "It has not been output. It has not been the impact."

That's certainly true when it comes to electricity. Afghanistan consumes less energy per person than any other country in the world, even after years of reconstruction efforts, according to data compiled by the U.S. government.

The $305 million diesel power plant, which has dubbed the most expensive plant of its type in the world, represents the biggest single investment the U.S. has made thus far to light up the country.

In 2007, the U.S. had rushed to build the plant in time to help Karzai win re-election, a hectic and unrealistic timetable embraced by the Afghan president that led to the jarring cost increases.

Complaints had piled up about Karzai's inability to deliver reliable power to Kabul, let alone the rest of the country.

"That question became very loud in many people's mind, and the media and the press, 'They haven't been able to bring power to Kabul,'" says Ahmad Wali Shairzay, Afghanistan's former deputy minister of water and energy.

The U.S. and other international donors had spent years helping Afghanistan develop an energy strategy, one focused on reducing the country's reliance on diesel as a primary power source, since it was too costly and too hard to acquire.

The goal was to buy cheaper electricity from neighboring countries and develop Afghanistan's own natural resources, such as water, natural gas and coal.

All of that was abandoned with the decision by U.S. and Afghan officials to build the diesel plant on the outskirts of Kabul.

Never mind that the plant would make the country more, not less, reliant on its fickle neighbors for power. Never mind that Karzai's former finance minister pleaded with U.S. officials to drop the idea.

The U.S. plowed ahead, turning the project over to a pair of American contractors, including one already scolded for wasting millions in taxpayer dollars on shoddy reconstruction projects. The U.S. team paid $109 million for 18 new diesel engines to be built — more than the original cost of the plant — only to discover rust and corrosion in several of them.

"The Kabul diesel project was sinful," says Mary Louise Vitelli, a U.S. energy consultant who focused on power development in Afghanistan for six years, working with the U.S., the World Bank and as a special adviser to Karzai's government.

James Bever, the U.S. Agency for International Development's director of the Afghanistan-Pakistan task force, says it's unfair to label the project a failure. Even with the problems, he notes, the plant provides Afghanistan with an additional power source.

"You know, there's a formula in this business. You can have it fast, you can have it high quality, and you can have it low cost. But you cannot have all three at the same time," Bever says.

For Afghans, each nightfall is a reminder of promises not kept.

When darkness comes, there is not much Abdul Rahim and others living in southwest Kabul can do. Without lights, they cannot work, and their children cannot play. Rahim's children sometimes sit around a kerosene lamp to do their homework, their books laid flat in a circle around the flame's flickering light.

"The people who are living in this area, they don't have electricity and it is dark everywhere," Rahim says. "Day and night, we are counting the minutes to when we will finally get electricity."

The setbacks stretch far beyond Kabul.

Despite spending millions of dollars over more than six years studying the nation's natural gas fields in the north, no plan is in place to tap that substantial resource for power. And a huge project to expand hydropower in the south that already has cost about $90 million is delayed by continued fighting in the region, which has long been a Taliban stronghold.

Only 497,000 of the country's 4.8 million households are connected to what passes for a national power grid, despite more than $1.6 billion already spent on energy projects, according to data from the country's utility corporation.

The system is more like a disconnected patchwork of pockets of available electricity, serving different regions of the country, some with hydropower, some with power imported from nearby countries and some with diesel-generated power.

So Afghans improvise at home, and many hotels and businesses — even embassies and international agencies — rely on their own generators for power. And some sell electricity to their neighbors.

Take Qurban Ali's old, crank-operated diesel generator, which coughs and belches black smoke before the engine starts running. His generator provides electricity to more than 100 houses in the Dasht-i-barchi neighborhood in Kabul, where Rahim lives.

"Right now, we are hopeless to have electricity," Ali says.

Afghans who can afford it pay private generator owners by the light bulb, about $2.60 a month for each bulb hanging from the ceiling. It costs nearly $11 a month to power a television. The average income in Afghanistan is a little more than a dollar a day.

The diesel plant that was supposed to serve Kabul was not ready to be turned over to the Afghan government until May 2010. Today, it runs mostly only for short periods, producing only a fraction of its promised 100 million watts of power.

"This power plant is too expensive for us to use," says Shojauddin Ziaie, Afghanistan's current deputy minister of water and energy.

U.S. contractor Black & Veatch oversaw the project for USAID as part of a joint $1.4 billion contract with The Louis Berger Group, another American contractor.

As the plant's costs and schedule veered wildly off course, the payouts to Black & Veatch also ballooned.

USAID refused to disclose the amounts paid as costs increased, but contract records obtained by The Associated Press show expenses and fees paid to the company tripled from $15.3 million in July 2007, when the project was estimated at $125.8 million overall, to $46.2 million in October 2009, when the price tag reached $301 million.

Greg Clum, a Black & Veatch vice president, defended the project, calling the plant a "critical piece in our ability to help Afghanistan get its legs under itself and to be able to become a sustainable, growing economic player in the region."

Black & Veatch and The Louis Berger group landed the contract in 2006.

The next year, congressional investigators chastised Berger's work on an earlier contract to build schools and health clinics, accusing the company of poor performance and misrepresenting work.

USAID also found problems with the two companies under their current contract, which an internal assessment found put too much risk on the agency and too little on the contractors, who had no incentive to control spending.

In March 2009, with more than half of the $1.4 billion already committed, the agency said it had "lost confidence" in the companies' abilities to do reconstruction work in Afghanistan. Yet the contract continues, with both the agency and the contractors saying management has improved.

"We had a rough patch," says Larry Walker, president of Louis Berger.

Shairzay, the former deputy energy minister, says Afghans view the diesel plant as a nice, expensive gift.

"Instead of giving me a small car, you give me really a Jaguar," he says. "And it will be up to me whether I use it, or just park it and look at it."

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BC Hydro says three LNG companies continue to demand electricity, justifying Site C

BC Hydro LNG Load Forecast signals rising electricity demand from LNG Canada, Woodfibre, and Tilbury, aligning Site C dam capacity with BCUC review, hydroelectric supply, and a potential fourth project in feasibility study British Columbia.

 

Key Points

BC Hydro's projection of LNG-driven power demand, guiding Site C capacity, BCUC review, and grid planning.

✅ Includes LNG Canada, Woodfibre, and Tilbury load requests

✅ Aligns Site C hydroelectric output with industrial electrification

✅ Notes feasibility study for a fourth LNG project

 

Despite recent project cancellations, such as the Siwash Creek independent power project now in limbo, BC Hydro still expects three LNG projects — and possibly a fourth, which is undergoing a feasibility study — will need power from its controversial and expensive Site C hydroelectric dam.

In a letter sent to the British Columbia Utilities Commission (BCUC) on Oct. 3, BC Hydro’s chief regulatory officer Fred James said the provincially owned utility’s load forecast includes power demand for three proposed liquefied natural gas projects because they continue to ask the company for power.

The letter and attached report provide some detail on which of the LNG projects proposed in B.C. are more likely to be built, given recent project cancellations.

The documents are also an attempt to explain why BC Hydro continues to forecast a surge in electricity demand in the province, as seen in its first call for power in 15 years driven by electrification, even though massive LNG projects proposed by Malaysia’s state owned oil company Petronas and China’s CNOOC Nexen have been cancelled.

An explanation is needed because B.C.’s new NDP government had promised the BCUC would review the need for the $9-billion Site C dam, which was commissioned to provide power for the province’s nascent LNG industry, amid debates over alternatives like going nuclear among residents. The commission had specifically asked for an explanation of BC Hydro’s electric load forecast as it relates to LNG projects by Wednesday.

The three projects that continue to ask BC Hydro for electricity are Shell Canada Ltd.’s LNG Canada project, the Woodfibre LNG project and a future expansion of FortisBC’s Tilbury LNG storage facility.

None of those projects have officially been sanctioned but “service requests from industrial sector customers, including LNG, are generally included in our industrial load forecast,” the report noted, even as Manitoba Hydro warned about energy-intensive customers in a separate notice.

In a redacted section of the report, BC Hydro also raises the possibility of a fourth LNG project, which is exploring the need for power in B.C.

“BC Hydro is currently undertaking feasibility studies for another large LNG project, which is not currently included in its Current Load Forecast,” one section of the report notes, though the remainder of the section is redacted.

The Site C dam, which has become a source of controversy in B.C. and was an important election issue, is currently under construction and, following two new generating stations recently commissioned, is expected to be in service by 2024, a timeline which had been considered to provide LNG projects with power by the time they are operational.

BC Hydro’s letter to the BCUC refers to media and financial industry reports that indicate global LNG markets will require more supply by 2023.

“While there remains significant uncertainty, global LNG demand will continue to grow and there is opportunity for B.C. LNG,” the report notes.

 

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Opinion: Germany's drive for renewable energy is a cautionary tale

Germany Energiewende Lessons highlight climate policy tradeoffs, as renewables, wind and solar face grid constraints, coal phase-out delays, rising electricity prices, and public opposition, informing Canada on diversification, hydro, oil and gas, and balanced transition.

 

Key Points

Insights from Germany's renewable shift on costs, grid limits, and emissions to guide Canada's balanced energy policy.

✅ Evidence: high power prices, delayed coal exit, limited grid buildout

✅ Land, materials, and wildlife impacts challenge wind and solar scale-up

✅ Diversification: hydro, nuclear, gas, and storage balance reliability

 

News that Greta Thunberg is visiting Alberta should be welcomed by all Canadians.

The teenaged Swedish environmentalist has focused global attention on the climate change debate like never before. So as she tours our province, where selling renewable energy could be Alberta's next big thing, what better time for a reality check than to look at a country that is furthest ahead in already adapting steps that Greta is advocating.

That country is Germany. And it’s not a pretty sight.

Germany embraced the shift toward renewable energy before anyone else, and did so with gusto. The result?

Germany’s largest newsmagazine Der Spiegel published an article on May 3 of this year entitled “A Botched Job in Germany.” The cover showed broken wind turbines and half-finished transition towers against a dark silhouette of Berlin.

Germany’s renewable energy transition, Energiewende, is a bust. After spending and committing a total of US$580 billion to it from 2000 to 2025.

Why is that? Because it’s been a nightmare of foolish dreams based on hope rather than fact, resulting in stalled projects and dreadfully poor returns.

Last year Germany admitted it had to delay its phase-out of coal and would not meet its 2020 greenhouse gas emissions reduction commitment. Only eight per cent of the transmission lines needed to support this new approach to powering Germany have been built.

Opposition to renewables is growing due to electricity prices rising to the point they are now among the highest in the world. Wind energy projects in Germany are now facing the same opposition that pipelines are here in Canada. 

Opposition to renewables in Germany, reports Forbes, is coming from people who live in rural or suburban areas, in opposition to the “urbane, cosmopolitan elites who fetishize their solar roofs and Teslas as a sign of virtue.” Sound familiar?

So, if renewables cannot successfully power Germany, one of the richest and most technologically advanced countries in the world, who can do it better?

The biggest problem with using wind and solar power on a large scale is that the physics just don’t work. They need too much land and equipment to produce sufficient amounts of electricity.

Solar farms take 450 times more land than nuclear power plants to produce the same amount of electricity. Wind farms take 700 times more land than natural gas wells.

The amount of metal required to build these sites is enormous, requiring new mines. Wind farms are killing hundreds of endangered birds.

No amount of marketing or spin can change the poor physics of resource-intensive and land-intensive renewables.

But, wait. Isn’t Norway, Greta’s neighbour, dumping its energy investments and moving into alternative energy like wind farms in a big way?

No, not really. Fact is only 0.8 per cent of Norway’s power comes from wind turbines. The country is blessed with a lot of hydroelectric power, but that’s a historical strength owing to the country’s geography, nothing new.

And yet we’re being told the US$1-trillion Oslo-based Government Pension Fund Global is moving out of the energy sector to instead invest in wind, solar and other alternative energy technologies. According to 350.org activist Nicolo Wojewoda this is “yet another nail in the coffin of the coal, oil, and gas industry.”

Well, no.

Norway’s pension fund is indeed investing in new energy forms, but not while pulling out of traditional investments in oil and gas. Rather, as any prudent fund manager will, they are diversifying by making modest investments in emerging industries such as Alberta's renewable energy surge that will likely pay off down the road while maintaining existing investments, spreading their investments around to reduce risk. Unfortunately for climate alarmists, the reality is far more nuanced and not nearly as explosive as they’d like us to think.

Yet, that’s enough for them to spin this tale to argue Canada should exit oil and gas investment and put all of our money into wind and solar, even as Canada remains a solar power laggard according to experts.

That is not to say renewable energy projects like wind and solar don’t have a place. They do, and we must continue to innovate and research lower-polluting ways to power our societies on the path to zero-emissions electricity by 2035 in Canada.

But like it actually is in Norway, investment in renewables should supplement — not replace — fossil fuel energy systems if we aim for zero-emission electricity in Canada by 2035 without undermining reliability. We need both.

And that’s the message that Greta should hear when she arrives in Canada.

Rick Peterson is the Edmonton-based founder and Beth Bailey is a Calgary-based supporter of Suits and Boots, a national not-for-profit group of investment industry professionals that supports resource sector workers and their families.

 

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Washington State Ferries' Hybrid-Electric Upgrade

Washington State Hybrid-Electric Ferries advance green maritime transit with battery-diesel propulsion, lower emissions, and fleet modernization, integrating charging infrastructure and reliable operations across WSF routes to meet climate goals and reduce fuel consumption.

 

Key Points

New WSF vessels using diesel-battery propulsion to cut emissions, improve efficiency, and sustain reliable ferry service.

✅ Hybrid diesel-battery propulsion reduces fuel use and CO2

✅ Larger vessels with efficient batteries and charging upgrades

✅ Compatible with WSF docks, maintenance, and safety standards

 

Washington State is embarking on an ambitious update to its ferry fleet, introducing hybrid-electric boats that represent a significant leap toward greener and more sustainable transportation. The state’s updated plans reflect a commitment to reducing carbon emissions and enhancing environmental stewardship while maintaining the efficiency and reliability of its vital ferry services.

The Washington State Ferries (WSF) system, one of the largest in the world, has long been a critical component of the state’s transportation network, linking various islands and coastal communities with the mainland. Traditionally powered by diesel engines, the ferries are responsible for significant greenhouse gas emissions. In response to growing environmental concerns and legislative pressure, WSF is now turning to hybrid-electric technology similar to battery-electric high-speed ferries seen elsewhere to modernize its fleet and reduce its carbon footprint.

The updated plans for the hybrid-electric boats build on earlier efforts to introduce cleaner technologies into the ferry system. The new designs incorporate advanced hybrid-electric propulsion systems that combine traditional diesel engines with electric batteries. This hybrid approach allows the ferries to operate on electric power during certain segments of their routes, reducing reliance on diesel fuel and cutting emissions as electric ships on the B.C. coast have demonstrated during similar operations.

One of the key features of the updated plans is the inclusion of larger and more capable hybrid-electric ferries, echoing BC Ferries hybrid ships now entering service in the region. These vessels are designed to handle the demanding operational requirements of the Washington State Ferries system while significantly reducing environmental impact. The new boats will be equipped with state-of-the-art battery systems that can store and utilize electric power more efficiently, leading to improved fuel economy and lower overall emissions.

The transition to hybrid-electric ferries is driven by both environmental and economic considerations. On the environmental side, the move aligns with Washington State’s broader goals to combat climate change and reduce greenhouse gas emissions, including programs like electric vehicle rebate program that encourage cleaner travel across the state. The state has set ambitious targets for reducing carbon emissions across various sectors, and upgrading the ferry fleet is a crucial component of achieving these goals.

From an economic perspective, hybrid-electric ferries offer the potential for long-term cost savings. Although the initial investment in new technology can be substantial, with financing models like CIB support for B.C. electric ferries helping spur adoption and reduce barriers for agencies, the reduced fuel consumption and lower maintenance costs associated with hybrid-electric systems are expected to lead to significant savings over the lifespan of the vessels. Additionally, the introduction of greener technology aligns with public expectations for more sustainable transportation options.

The updated plans also emphasize the importance of integrating hybrid-electric technology with existing infrastructure. Washington State Ferries is working to ensure that the new vessels are compatible with current docking facilities and maintenance practices. This involves updating docking systems, as seen with Kootenay Lake electric-ready ferry preparations, to accommodate the specific needs of hybrid-electric ferries and training personnel to handle the new technology.

Public response to the hybrid-electric ferry initiative has been largely positive, with many residents and environmental advocates expressing support for the move towards greener transportation. The new boats are seen as a tangible step toward reducing the environmental impact of one of the state’s most iconic transportation services. The project also highlights Washington State’s commitment to innovation and leadership in sustainable transportation, alongside global examples like Berlin's electric flying ferry that push the envelope in maritime transit.

However, the transition to hybrid-electric ferries is not without its challenges. Implementing new technology requires careful planning and coordination, including addressing potential technical issues and ensuring that the vessels meet all safety and operational standards. Additionally, there may be logistical challenges associated with integrating the new ferries into the existing fleet and managing the transition without disrupting service.

Despite these challenges, the updated plans for hybrid-electric boats represent a significant advancement in Washington State’s efforts to modernize its transportation system. The initiative reflects a growing trend among transportation agencies to embrace sustainable technologies and address the environmental impact of traditional transportation methods.

In summary, Washington State’s updated plans for hybrid-electric ferries mark a crucial step towards a more sustainable and environmentally friendly transportation network. By incorporating advanced hybrid-electric technology, the state aims to reduce carbon emissions, improve fuel efficiency, and align with its broader climate goals. While challenges remain, the initiative demonstrates a commitment to innovation and underscores the importance of transitioning to greener technologies in the quest for a more sustainable future.

 

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Taiwan's economic minister resigns over widespread power outage

Taiwan Power Blackout disrupts Taipei and commercial hubs after a Taoyuan natural gas plant error, triggering nationwide outage, grid failure, elevator rescues, power rationing, and the economic minister's resignation, as CPC Corporation restores supply.

 

Key Points

A nationwide Taiwan outage from human error at a Taoyuan gas plant, triggering rationing and a minister's resignation.

✅ Human error disrupted natural gas supply at Taoyuan plant

✅ 6.68 million users affected; grid failure across cities

✅ Minister Lee resigned; President Tsai ordered a review

 

Taiwan's economic minister resigned after power was knocked out in many parts of Taiwan, with regional parallels such as China power cuts highlighting grid vulnerabilities, including capital Taipei's business and high-end shopping district, due to an apparent "human error" at a key power plant.

Economic Affairs minister Lee Chih-kung tendered his resignation verbally to Premier Lin Chuan, United Daily News reported, citing a Cabinet spokesman. Lin accepted the resignation, the spokesman said according to the daily.

As many as 6.68 million households and commercial units saw their power supply cut or disrupted on Tuesday after "human error" disrupted natural gas supply at a power plant in northern Taiwan's Taoyuan, the semi-official Central News Agency reported, citing the government-controlled oil company CPC Corporation as saying.

The company added that power at the plant, Taiwan's biggest natural gas power plant, resumed two minutes later.

In New Taipei City, there were at least 27,000 reported cases of people being stuck in lifts. Photos in social media also showed huge crowds stranded in lift lobby in Taipei's iconic 101-storey Taipei 101 building.

Power rationing was implemented beginning 6pm, and, as seen in the National Grid short supply warning in other markets, such steps aim to stabilize supply, Central News Agency said. Power supply was gradually being restored beginning at about 9:40pm. news reports said.

President Tsai Ing-wen apologised for the blackout, noting parallels with Japan's near-blackouts that underscored grid resilience, and said that she has ordered all relevant departments to produce clear report in the shortest time possible.

"Electricity is not just a problem about people's livelihoods but also a national security issue. A comprehensive review must be carried out to find out how the electric power system can be so easily paralysed by human error," said Ms Tsai in a Facebook post.

Taiwan has been at risk of a power shortage after a recent typhoon knocked down a power transmission tower in Hualien county along the eastern coast of Taiwan, rather than a demand-driven slowdown like the China power demand drop during pandemic factory shutdowns. This reduced the electricity supply by 1.3million kilowatts, or about 4 per cent of the operating reserve.

That was followed by the breakdown of a power generator at Taiwan's largest power plant, which further reduced the operating reserve by 1.5 per cent.

The situation is worsened by the ongoing heatwave that has hit Taiwan, with temperatures soaring to 38 degrees Celsius over the past week.

As a result, the government had imposed the rationing of electricity, and, highlighting how regional strains such as China's power woes can ripple into global markets, switched off all air-conditioning in many of its Taipei offices, a move that drew some public backlash.

 

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Only one in 10 utility firms prioritise renewable electricity – global study

Utility Renewable Investment Gap highlights Oxford study in Nature Energy: most electric utilities favor fossil fuels over clean energy transition, expanding coal and gas, risking stranded assets and missing climate targets despite global decarbonization commitments.

 

Key Points

Most utilities grow fossil capacity over renewables, slowing decarbonization and jeopardizing climate goals.

✅ Only 10% expand renewables faster than coal and gas growth

✅ 60% still add fossil plants; 15% actively cut coal and gas

✅ Risks: stranded assets, missed climate targets, policy backlash

 

Only one in 10 of the world’s electric utility companies are prioritising clean energy investment over growing their capacity of fossil fuel power plants, according to research from the University of Oxford.

The study of more than 3,000 utilities found most remain heavily invested in fossil fuels despite international efforts to reduce greenhouse gas emissions and barriers to 100% renewables in the US that persist, and some are actively expanding their portfolio of polluting power plants.

The majority of the utility companies, many of which are state owned, have made little change to their generation portfolio in recent years.

Only 10% of the companies in the study, published in the research journal Nature Energy, are expanding their renewable energy capacity, mirroring global wind and solar growth patterns, at a faster rate than their gas- or coal-fired capacity.

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Of the companies prioritising renewable energy growth, 60% have not stopped concurrently expanding their fossil fuel portfolio and only 15% of these companies are actively reducing their gas and coal capacity.

Galina Alova, the author of the report, said the research highlighted “a worrying gap between what is needed” to tackle the climate crisis, with calls for a fossil fuel lockdown gaining attention, and “what actions are being taken by the utility sector”.

The report found 10% of utilities were favouring growth in gas-fired power plants. This cluster is dominated by US utilities, even as renewables surpass coal in US generation in the broader market, eager to take advantage of the country’s shale gas reserves, followed by Russia and Germany.

Only 2% of utilities are actively growing their coal-fired power capacity ahead of renewables or gas. This cluster is dominated by Chinese utilities – which alone contributed more than 60% of coal-focused companies – followed by India and Vietnam.

The report found the majority of companies prioritising renewable energy were clustered in Europe. Many of the industry’s biggest players are investing in low-carbon energy and green technologies, even as clean energy's dirty secret prompts debate, to replace their ageing fossil fuel power plants.


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In the UK, amid UK renewables backlog that has stalled billions, coal plants are shutting at pace ahead of the government’s 2025 ban on coal-fired power in part because the UK’s domestic carbon tax on power plants make them uneconomic to run.

“Although there have been a few high-profile examples of individual electric utilities investing in renewables, this study shows that overall, the sector is making the transition to clean energy slowly or not at all,” Alova said.

“Utilities’ continued investment in fossil fuels leaves them at risk of stranded assets – where power plants will need to be retired early – and undermines global efforts to tackle climate change.”
 

 

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Shell’s strategic move into electricity

Shell's Industrial Electricity Supply Strategy targets UK and US industrial customers, leveraging gas-to-power, renewables, long-term PPAs, and energy transition momentum to disrupt utilities, cut costs, and secure demand in the evolving electricity market.

 

Key Points

Shell will sell power directly to industrial clients, leveraging gas, renewables, and PPAs to secure demand and pricing.

✅ Direct power sales to industrials in UK and US

✅ Leverages gas-to-power, renewables, and flexible sourcing

✅ Targets long-term PPAs, price stability, and demand security

 

Royal Dutch Shell’s decision to sell electricity direct to industrial customers is an intelligent and creative one. The shift is strategic and demonstrates that oil and gas majors are capable of adapting to a new world as the transition to a lower carbon economy develops. For those already in the business of providing electricity it represents a dangerous competitive threat. For the other oil majors it poses a direct challenge on whether they are really thinking about the future sufficiently strategically.

The move starts small with a business in the UK that will start trading early next year, in a market where the UK’s second-largest electricity operator has recently emerged, signaling intensifying competition. Shell will supply the business operations as a first step and it will then expand. But Britain is not the limit — Shell recently announced its intention of making similar sales in the US. Historically, oil and gas companies have considered a move into electricity as a step too far, with the sector seen as oversupplied and highly politicised because of sensitivity to consumer price rises. I went through three reviews during my time in the industry, each of which concluded that the electricity business was best left to someone else. What has changed? I think there are three strands of logic behind the strategy.

First, the state of the energy market. The price of gas in particular has fallen across the world over the last three years to the point where the International Energy Agency describes the current situation as a “glut”. Meanwhile, Shell has been developing an extensive range of gas assets, with more to come. In what has become a buyer’s market it is logical to get closer to the customer — establishing long-term deals that can soak up the supply, while options such as storing electricity in natural gas pipes gain attention in Europe. Given its reach, Shell could sign contracts to supply all the power needed by the UK’s National Health Service or with the public sector as a whole as well as big industrial users. It could agree long-term contracts with big businesses across the US.

To the buyers, Shell offers a high level of security from multiple sources with prices presumably set at a discount to the market. The mutual advantage is strong. Second, there is the transition to a lower carbon world. No one knows how fast this will move, but one thing is certain: electricity will be at the heart of the shift with power demand increasing in transportation, industry and the services sector as oil and coal are displaced. Shell, with its wide portfolio, can match inputs to the circumstances and policies of each location. It can match its global supplies of gas to growing Asian markets, including China’s 2060 electricity share projections, while developing a renewables-based electricity supply chain in Europe. The new company can buy supplies from other parts of the group or from outside. It has already agreed to buy all the power produced from the first Dutch offshore wind farm at Egmond aan Zee.

The move gives Shell the opportunity to enter the supply chain at any point — it does not have to own power stations any more than it now owns drilling rigs or helicopters. The third key factor is that the electricity market is not homogenous. The business of supplying power can be segmented. The retail market — supplying millions of households — may be under constant scrutiny, as efforts to fix the UK’s electricity grid keep infrastructure in the headlines, with suppliers vilified by the press and governments forced to threaten price caps but supplying power to industrial users is more stable and predictable, and done largely out of the public eye. The main industrial and commercial users are major companies well able to negotiate long-term deals.

Given its scale and reputation, Shell is likely to be a supplier of choice for industrial and commercial consumers and potentially capable of shaping prices. This is where the prospect of a powerful new competitor becomes another threat to utilities and retailers whose business models are already under pressure. In the European market in particular, electricity pricing mechanisms are evolving and public policies that give preference to renewables have undermined other sources of supply — especially those produced from gas. Once-powerful companies such as RWE and EON have lost much of their value as a result. In the UK, France and elsewhere, public and political hostility to price increases have made retail supply a risky and low-margin business at best. If the industrial market for electricity is now eaten away, the future for the existing utilities is desperate.

Shell’s move should raise a flag of concern for investors in the other oil and gas majors. The company is positioning itself for change. It is sending signals that it is now viable even if oil and gas prices do not increase and that it is not resisting the energy transition. Chief executive Ben van Beurden said last week that he was looking forward to his next car being electric. This ease with the future is rather rare. Shareholders should be asking the other players in the old oil and gas sector to spell out their strategies for the transition.

 

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