China aims to reduce coal power production


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China Coal-Fired Power Consolidation targets capacity cuts through mergers, SASAC-led restructuring, debt reduction, asset optimization, and retiring inefficient plants across state-owned utilities to improve efficiency, stabilize liabilities, and align with energy transition policies.

 

Key Points

A SASAC-driven plan merging utility assets to cut coal capacity, reduce debt, and retire outdated, loss-making plants.

✅ Merge five central utilities' coal assets to streamline operations

✅ Target 25-33% capacity cuts and >50% loss reduction by 2021

✅ Prioritize debt-ridden regions: Gansu, Shaanxi, Xinjiang, Qinghai, Ningxia

 

China plans to slash coal-fired power capacity at its five biggest utilities by as much as a third in two years by merging their assets, amid broader power-sector strains that reverberate globally, according to a document seen by Reuters and four sources with knowledge of the matter.

The move to shed older and less-efficient capacity is being driven by pressure to cut heavy debt levels at the utilities. China, is, however, building more coal-fired power plants and approving dozens of new mines to bolster a slowing economy, even as recent power cuts highlight grid imbalances.

The five utilities, which are controlled by the central government, accounted for around 44% of China’s total coal-fired power capacity at the end of 2018, a share likely to be tested by rising electrification goals, with electricity to meet 60% by 2060 according to industry forecasts.

“(The utilities) will strive to reduce coal-fired power capacity by one quarter to one third ...cutting total losses by more than 50% from the current level to achieve a significant decline in debt-to-asset ratios by the end of 2021,” the document said.

The plan, initiated and overseen by the State-owned Assets Supervision and Administration Commission of the State Council (SASAC), follows heavy losses at some of the utilities, amid a pandemic-era demand drop that hit industrial consumption.

Some of their coal-fired power stations have filed for bankruptcy in recent years as Beijing promotes the use of renewable energy and advances its nuclear program while opening up the state-controlled power market.

The SASAC did not immediately respond to a fax seeking comment and the sources declined to be identified as they were not authorised to speak to the media.

The utilities - China Huaneng Group Co, China Datang Corp, China Huadian Corp, State Power Investment Corp and China Energy Group - did not respond to faxes requesting comment.

Together, they had 474 coal-fired power plants with combined power generation capacity of 520 gigawatts (GW) at the end of last year.

Their coal-fired power assets came to 1.5 trillion yuan ($213 billion) while total coal-fired power liabilities were 1.1 trillion yuan, the document said.

The document was seen by two people at two of the utilities and was also verified by a source at SASAC and a government researcher.

It was not clear when the document was published but it said the merging and elimination of outdated capacity would start from 2019 and be achieved within three years, aiming to improve the efficiency and operations at the companies, reflecting a broader electricity sector mystery that policymakers are trying to resolve.

Utilities with debt-ridden operations in the northwestern regions of Gansu, Shaanxi, Xinjiang, Qinghai and Ningxia would be the first to carry out the plan, it said, even as India ration coal supplies during demand surges.

The government researcher said the SASAC has been researching possible consolidation in the coal-fired power sector since 2017, but added: “It’s easier said than done.”

“No one is willing to hand in their high quality assets and there is no point in merging the bad assets,” the government researcher said.

 

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As New Zealand gets serious about climate change, can electricity replace fossil fuels in time?

New Zealand Energy Transition will electrify transport and industry with renewables, grid-scale solar, wind farms, geothermal, batteries, demand response, pumped hydro, and transmission upgrades to manage dry-year risk and winter peak loads.

 

Key Points

A shift to renewables and smart demand to decarbonise transport and industry while ensuring reliable, affordable power.

✅ Electrifies transport and industrial heat with renewables

✅ Uses demand response, batteries, and pumped hydro for resilience

✅ Targets 99%+ renewable supply, managing dry-year and peak loads

 

As fossil fuels are phased out over the coming decades, the Climate Change Commission (CCC) suggests electricity will take up much of the slack, aligning with the vision of a sustainable electric planet powering our vehicle fleet and replacing coal and gas in industrial processes.

But can the electricity system really provide for this increased load where and when it is needed? The answer is “yes”, with some caveats.

Our research examines climate change impacts on the New Zealand energy system. It shows we’ll need to pay close attention to demand as well as supply. And we’ll have to factor in the impacts of climate change when we plan for growth in the energy sector.

 

Demand for electricity to grow
While electricity use has not increased in NZ in the past decade, many agencies project steeply rising demand in coming years. This is partly due to both increasing population and gross domestic product, but mostly due to the anticipated electrification of transport and industry, which could result in a doubling of demand by mid-century.

It’s hard to get a sense of the scale of the new generation required, but if wind was the sole technology employed to meet demand by 2050, between 10 and 60 new wind farms would be needed nationwide.

Of course, we won’t only build wind farms, as renewables are coming on strong and grid-scale solar, rooftop solar, new geothermal, some new small hydro plant and possibly tidal and wave power will all have a part to play.

 

Managing the demand
As well as providing more electricity supply, demand management and batteries will also be important. Our modelling shows peak demand (which usually occurs when everyone turns on their heaters and ovens at 6pm in winter) could be up to 40% higher by 2050 than it is now.

But meeting this daily period of high demand could see expensive plant sitting idle for much of the time (with the last 25% of generation capacity only used about 10% of the time).

This is particularly a problem in a renewable electricity system when the hydro lakes are dry, as hydro is one of the few renewable electricity sources that can be stored during the day (as water behind the dam) and used over the evening peak (by generating with that stored water).

Demand response will therefore be needed. For example, this might involve an industrial plant turning off when there is too much load on the electricity grid.

 

But by 2050, a significant number of households will also need smart appliances and meters that automatically use cheaper electricity at non-peak times. For example, washing machines and electric car chargers could run automatically at 2am, rather than 6pm when demand is high.

Our modelling shows a well set up demand response system could mitigate dry-year risk (when hydro lakes are low on water) in coming decades, where currently gas and coal generation is often used.

Instead of (or as well as) having demand response and battery systems to combat dry-year risk, a pumped storage system could be built. This is where water is pumped uphill when hydro lake inflows are plentiful, and used to generate electricity during dry periods.

The NZ Battery project is currently considering the potential for this in New Zealand, and debates such as whether we would use Site C's electricity offer relevant lessons.

 

Almost (but not quite) 100% renewable
Dry-year risk would be greatly reduced and there would be “greater greenhouse gas emissions savings” if the Interim Climate Change Committee’s (ICCC) 2019 recommendation to aim for 99% renewable electricity was adopted, rather than aiming for 100%.

A small amount of gas-peaking plant would therefore be retained. The ICCC said going from 99% to 100% renewable electricity by overbuilding would only avoid a very small amount of carbon emissions, at a very high cost.

Our modelling supports this view. The CCC’s draft advice on the issue also makes the point that, although 100% renewable electricity is the “desired end point”, timing is important to enable a smooth transition.

Despite these views, Energy Minister Megan Woods has said the government will be keeping the target of a 100% renewable electricity sector by 2030.

 

Impacts of climate change
In future, the electricity system will have to respond to changing climate patterns as well, becoming resilient to climate risks over time.

The National Institute of Water and Atmospheric Research predicts winds will increase in the South Island and decrease in the far north in coming decades.

Inflows to the biggest hydro lakes will get wetter (more rain in their headwaters), and their seasonality will change due to changes in the amount of snow in these catchments.

Our modelling shows the electricity system can adapt to those changing conditions. One good news story (unless you’re a skier) is that warmer temperatures will mean less snow storage at lower elevations, and therefore higher lake inflows in the big hydro catchments in winter, leading to a better match between times of high electricity demand and higher inflows.

 

The price is right
The modelling also shows the cost of generating electricity is not likely to increase, because the price of building new sources of renewable energy continues to fall globally.

Because the cost of building new renewables is now cheaper than non-renewables (such as coal-fired plants), investing in carbon-free electricity is increasingly compelling, and renewables are more likely to be built to meet new demand in the near term.

While New Zealand’s electricity system can enable the rapid decarbonisation of (at least) our transport and industrial heat sectors, international efforts like cleaning up Canada's electricity underline the need for certainty so the electricity industry can start building to meet demand everywhere.

Bipartisan cooperation at government level will be important to encourage significant investment in generation and transmission projects with long lead times and life expectancies, as analyses of climate policy and grid implications underscore in comparable markets.

Infrastructure and markets are needed to support demand response uptake, as well as certainty around the Tiwai exit in 2024 and whether pumped storage is likely to be built.

Our electricity system can support the rapid decarbonisation needed if New Zealand is to do its fair share globally to tackle climate change.

But sound planning, firm decisions and a supportive and relatively stable regulatory framework are all required before shovels can hit the ground.

 

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Electricity Regulation With Equity & Justice For All

Energy equity in utility regulation prioritizes fair rates, clean energy access, and DERs, addressing fixed charges and energy burdens on low-income households through stakeholder engagement and public utility commission reforms.

 

Key Points

Fairly allocates clean energy benefits and rate burdens, ensuring access and protections for low-income households.

✅ Reduces fixed charges that burden low-income households

✅ Funds community participation in utility proceedings

✅ Prioritizes DERs, energy efficiency, and solar in impacted areas

 

By Kiran Julin

Pouring over the line items on your monthly electricity bill may not sound like an enticing way to spend an afternoon, but the way electricity bills are structured has a significant impact on equitable energy access and distribution. For example, fixed fees can have a disproportionate impact on low-income households. And combined with other factors, low-income households and households of color are far more likely to report losing home heating service, with evidence from pandemic power shut-offs highlighting these disparities, according to recent federal data.

Advancing Equity in Utility Regulation, a new report published by the U.S. Department of Energy’s (DOE’s) Lawrence Berkeley National Laboratory (Berkeley Lab), makes a unifying case that utilities, regulators, and stakeholders need to prioritize energy equity in the deployment of clean energy technologies and resources, aligning with a people-and-planet electricity future envisioned by advocacy groups. Equity in this context is the fair distribution of the benefits and burdens of energy production and consumption. The report outlines systemic changes needed to advance equity in electric utility regulation by providing perspectives from four organizations — Portland General Electric, a utility company; the National Consumer Law Center, a consumer advocacy organization; and the Partnership for Southern Equity and the Center for Biological Diversity, social justice and environmental organizations.
 
“While government and ratepayer-funded energy efficiency programs have made strides towards equity by enabling low-income households to access energy-efficiency measures, that has not yet extended in a major way to other clean-energy technologies,” said Lisa Schwartz, a manager and strategic advisor at Berkeley Lab and technical editor of the report. “States and utilities can take the lead to make sure the clean-energy transition does not leave behind low-income households and communities of color. Decarbonization and energy equity goals are not mutually exclusive, and in fact, they need to go hand-in-hand.”

Energy bills and electricity rates are governed by state laws and utility regulators, whose mission is to ensure that utility services are reliable, safe, and fairly priced. Public utility commissions also are increasingly recognizing equity as an important goal, tool, and metric, and some customers face major changes to electric bills as reforms advance. While states can use existing authorities to advance equity in their decision-making, several, including Illinois, Maine, Oregon, and Washington, have enacted legislation over the last couple of years to more explicitly require utility regulators to consider equity.

“The infrastructure investments that utility companies make today, and regulator decisions about what goes into electricity bills, including new rate design steps that shape customer costs, will have significant impacts for decades to come,” Schwartz said.

Solutions recommended in the report include considering energy justice goals when determining the “public interest” in regulatory decisions, allocating funding for energy justice organizations to participate in utility proceedings, supporting utility programs that increase deployment of energy efficiency and solar for low-income households, and accounting for energy inequities and access in designing electricity rates, while examining future utility revenue models as technologies evolve.

The report is part of the Future of Electric Utility Regulation series that started in 2015, led by Berkeley Lab and funded by DOE, to encourage informed discussion and debate on utility trends and tackling the toughest issues related to state electric utility regulation. An advisory group of utilities, public utility commissioners, consumer advocates, environmental and social justice organizations, and other experts provides guidance.

 

Taking stock of past and current energy inequities

One focus of the report is electricity bills. In addition to charges based on usage, electricity bills usually also have a fixed basic customer charge, which is the minimum amount a household has to pay every month to access electricity. The fixed charge varies widely, from $5 to more than $20. In recent years, utility companies have sought sizable increases in this charge to cover more costs, amid rising electricity prices in some markets.

This fixed charge means that no matter what a household does to use energy more efficiently or to conserve energy, there is always a minimum cost. Moreover, low-income households often live in older, poorly insulated housing. Current levels of public and utility funding for energy-efficiency programs fall far short of the need. The combined result is that the energy burden – or percent of income needed to keep the lights on and their homes at a healthy temperature – is far greater for lower-income households.

“While all households require basic lighting, heating, cooling, and refrigeration, low-income households must devote a greater proportion of income to maintain basic service,” explained John Howat and Jenifer Bosco from the National Consumer Law Center and co-authors of Berkeley Lab’s report. Their analysis of data from the most recent U.S. Energy Information Administration’s Residential Energy Consumption Survey shows households with income less than $20,000 reported losing home heating service at a pace more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. In addition, low-income households and households of color are more likely to have to choose between paying their energy bill or paying for other necessities, such as healthcare or food.

Based on the most recent data (2015) from the U.S. Energy Information Administration (EIA), households with income less than $20,000 reported losing home heating service at a rate more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. Click on chart for larger view. (Credit: John Howat/National Consumer Law Center, using EIA data)

Moreover, while many of the infrastructure investment decisions that utilities make, such as whether and where to build a new power plant, often have long-term environmental and health consequences, impacted communities often are not at the table. “Despite bearing an inequitable proportion of the negative impacts of environmental injustices related to fossil fuel-based energy production and climate change, marginalized communities remain virtually unrepresented in the energy planning and decision-making processes that drive energy production, distribution, and regulation,” wrote Chandra Farley, CEO of ReSolve and a co-author of the report.


Engaging impacted communities
Each of the perspectives in the report identify a need for meaningful engagement of underrepresented and disadvantaged communities in energy planning and utility decision-making. “Connecting the dots between energy, racial injustice, economic disinvestment, health disparities, and other associated equity challenges becomes a clarion call for communities that are being completely left out of the clean energy economy,” wrote Farley, who previously served as the Just Energy Director at Partnership for Southern Equity. “We must prioritize the voices and lived experiences of residents if we are to have more equity in utility regulation and equitably transform the energy sector.”

In another essay in the report, Nidhi Thaker and Jake Wise from Portland General Electric identify the importance of collaborating directly with the communities they serve. In 2021, the Oregon Legislature passed Oregon HB 2475, which allows the Oregon Public Utility Commission to allocate ratepayer funding for organizations representing people most affected by a high energy burden, enabling them to participate in utility regulatory processes.

The report explains why energy equity requires correcting inequities resulting from past and present failures as well as rethinking how we achieve future energy and decarbonization goals. “Equity in energy requires adopting an expansive definition of the ‘public interest’ that encompasses energy, climate, and environmental justice. Energy equity also means prioritizing the deployment of distributed energy resources and clean energy technologies in areas that have been hit first and worst by the existing fossil fuel economy,” wrote Jean Su, energy justice director and senior attorney at the Center for Biological Diversity.

This report was supported by DOE’s Grid Modernization Laboratory Consortium, with funding from the Office of Energy Efficiency and Renewable Energy and the Office of Electricity.

 

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"Knowledge Gap" Is Contributing To On-the-job Electrical Injuries

BC Hydro Trades Electrical Safety addresses electric contact incidents among trade workers, emphasizing power line hazards, overhead lines clearance, the 3 m rule, jobsite planning, and safety training to prevent injuries during spring and summer.

 

Key Points

BC Hydro Trades Electrical Safety is guidance and training to reduce power-line contact risks for trade workers.

✅ Stay at least 3 m from overhead power lines and equipment

✅ Plan worksites and spot hazards before starting tasks

✅ Use BC Hydro electrical awareness training near electricity

 

A BC Hydro report finds serious electrical contact incidents are more common among trades workers, and research shows this is partly due to a knowledge gap in the electricity sector in Canada.

Trade workers were involved in more than 60 per cent of electric contact incidents that led to serious injuries over the last three years, according to BC Hydro.

One-in-five trade workers have also either made contact or had a close call with electric equipment.

A recent worksite electrocution case underscores the consequences of contact.

“New research finds many have had a close call with electricity on the job or have witnessed unsafe work near overhead lines or electrical equipment,” BC Hydro staff said in the report.

“A gap in electrical safety knowledge is a contributing factor in most of these incidents.”

Most electrical contact incidents take place in the spring and summer, when trade workers are working outdoors and are working in close proximity to power lines.

BC Hydro offered tips for trades workers who may work closely to possible electrical contact points:

  • Look up and down – Observe the site beforehand and plan work so you can avoid contact with power lines
  • Stay back – You and your tools should stay at least 3 m away from an overhead power line
  • Call for help – If you come across a fallen power line, or a tree branch or object contacts a line—stay back 10 metres and call 911. Never try and move it yourself. If you must work closer than 3 m to a power line at your worksite, call BC Hydro before you begin.
  • Learn about the risks – BC Hydro offers in-person and online electrical awareness training, such as arc flash training, for anyone who works near electricity.

The report found that 38 per cent of trades workers who participated in the report said they only feel “somewhat informed” about safety measures around working near electricity and 71 per cent were unable to identify the correct distance they should be away from active power lines or electrical equipment.

BC Hydro said trade workers should participate in its electrical awareness training courses, including arc flash training, to make sure all safety measures are taken.

 

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Gaza’s sole electricity plant shuts down after running out of fuel

Gaza Power Plant Shutdown underscores the Gaza Strip's fuel ban, Israeli blockade, and electricity crisis, cutting megawatts, disrupting hospitals and quarantine centers, and exposing fragile energy supply, GEDCO warnings, and public health risks.

 

Key Points

An abrupt halt of Gaza's sole power plant due to a fuel ban, deepening the electricity crisis and straining hospitals.

✅ Israeli fuel ban halts Gaza's only power plant

✅ Available supply drops far below 500 MW demand

✅ Hospitals and COVID-19 quarantine centers at risk

 

The only electricity plant in the Gaza Strip shut down yesterday after running out of fuel banned from entering the besieged enclave by the Israeli occupation, Gaza Electricity Distribution Company announced.

“The power plant has shut down completely,” the company said in a brief statement, as disruptions like China power cuts reveal broader grid vulnerabilities.

Israel banned fuel imports into Gaza as part of punitive measures over the launching incendiary balloons from the Strip.

On Sunday, GEDCO warned that the industrial fuel for the electricity plant would run out, mirroring Lebanon's fuel shortage challenges, on Tuesday morning.

Since 2007, the Gaza Strip suffered under a crippling Israeli blockade that has deprived its roughly two million inhabitants of many vital commodities, including food, fuel and medicine, and regional strains such as Iraq's summer electricity needs highlight broader power insecurity.

As a result, the coastal enclave has been reeling from an electricity crisis, similar to when the National Grid warned of short supply in other contexts.

The Gaza Strip needs some 500 megawatts of electricity – of which only 180 megawatts are currently available – to meet the needs of its population, while Iran supplies about 40% of Iraq's electricity in the region.

Spokesman of the Ministry of Health in Gaza, Ashraf Al Qidra, said the lack of electricity undermines offering health services across Gaza’s hospitals.

He also warned that the lack of electricity would affect the quarantine centres used for coronavirus patients, reinforcing the need to keep electricity options open during the pandemic.

Gaza currently has three sources of electricity: Israel, which provides 120 megawatts and is advancing coal use reduction measures; Egypt, which supplies 32 megawatts; and the Strip’s sole power plant, which generates between 40 and 60 megawatts.

 

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Ex-SpaceX engineers in race to build first commercial electric speedboat

Arc One Electric Speedboat delivers zero-emission performance, quiet operation, and reduced maintenance, leveraging battery propulsion, aerospace engineering, and venture-backed innovation to cut noise pollution, fuel costs, and water contamination in high-performance marine recreation.

 

Key Points

Arc One Electric Speedboat is a battery-powered, zero-emission craft offering quiet, high-performance marine cruising.

✅ 475 hp, 24 ft hull, about 40 mph top speed

✅ Cuts noise, fumes, and water contamination vs gas boats

✅ Backed by Andreessen Horowitz; ex-SpaceX engineers

 

A team of former SpaceX rocket engineers have joined the race to build the first commercial electric speedboat.

The Arc Boat company announced it had raised $4.25m (£3m) in seed funding to start work on a 24ft 475-horsepower craft that will cost about $300,000.

The LA-based company, which is backed by venture capital firm Andreessen Horowitz (an early backer of Facebook and Airbnb), said the first model of the Arc One boat would be available for sale by the end of the year.

Mitch Lee, Arc’s chief executive, said he wanted to build electric boats because of the impact conventional petrol- or diesel-powered boats have on the environment.

“They not only get just two miles to the gallon, they also pump a lot of those fumes into the water,” Lee said. “In addition, there is the huge noise pollution factor [of conventional boats] and that is awful for the marine life. With gas-powered boats it’s not just carbon emissions into the air, it’s also polluting the water and causing noise pollution. Electric boats, like electric ships clearing the air on the B.C. coast, eliminate all that.”

Lee said electric vessels would also reduce the hassle of boat ownership. “I love being out on the water, being on a boat is so much fun, but owning a boat is so awful,” he said. “I have always believed that electric boats make sense. They will be quicker, quieter and way cheaper and easier to operate and maintain, with access options like an electric boat club in Seattle lowering barriers for newcomers.”

While the first models will be very expensive, Lee said the cost was mostly in developing the technology and cheaper versions would be available in the future, mirroring advances in electric aviation seen across the industry. “It is very much the Tesla approach – we are starting up market and using that income to finance research and development and work our way down market,” he said.

Lee said the technology could be applied to larger craft, and even ferries could run on electricity in the future, as projects for battery-electric high-speed ferries begin to scale.

“We started in February with no team, no money and no warehouse,” he said. “By December we are going to be selling the Arc One, and we are hiring aggressively because we want to accelerate the adoption of electric boats across a whole range of craft, including an electric-ready ferry on Kootenay Lake.”

Lee founded the company with fellow mechanical engineer Ryan Cook. Cook, the company’s chief technology officer, was previously the lead mechanical engineer at Elon Musk’s space exploration company SpaceX where he worked on the Falcon 9 rocket, the world’s first orbital class reusable rocket. In parallel, Harbour Air's electric aircraft highlights cross-sector electrification. Apart from Lee, all of Arc’s employees have some experience working at SpaceX.

The Arc boat, which would have a top speed of 40 mph, joins a number of startups rushing to make the first large-scale production of electric-powered speedboats, while a Vancouver seaplane airline demonstrates complementary progress with a prototype electric aircraft. The Monaco Yacht Club this month held a competition for electric boat prototypes to “instigate a new vision and promote all positive approaches to bring yachting into line” with global carbon dioxide emission reduction targets. Sweden’s Candela C-7 hydrofoil boat was crowned the fastest electric vessel.

 

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BMW boss says hydrogen, not electric, will be "hippest thing" to drive

BMW Hydrogen Fuel Cell Strategy positions iX5 and eDrive for zero-emission mobility, leveraging fuel cells, fast refueling, and hydrogen infrastructure as an alternative to BEVs, diversifying drivetrains across premium segments globally, rapidly.

 

Key Points

BMW's plan to commercialize hydrogen fuel-cell drivetrains like iX5 eDrive for scalable, zero-emission mobility.

✅ Fuel cells enable fast refueling and long range with water vapor only.

✅ Reduces reliance on lithium and cobalt via recyclable materials.

✅ Targets premium SUV iX5; limited pilots before broader rollout.

 

BMW is hanging in there with hydrogen, a stance mirrored in power companies' hydrogen outlook today. That’s what Oliver Zipse, the chairperson of BMW, reiterated during an interview last week in Goodwood, England. 

“After the electric car, which has been going on for about 10 years and scaling up rapidly, the next trend will be hydrogen,” he says. “When it’s more scalable, hydrogen will be the hippest thing to drive.”

BMW has dabbled with the idea of using hydrogen for power for years, even though it is obscure and niche compared to the current enthusiasm surrounding vehicles powered by electricity. In 2005, BMW built 100 “Hydrogen 7” vehicles that used the fuel to power their V12 engines. It unveiled the fuel cell iX5 Hydrogen concept car at the International Motor Show Germany in 2021. 

In August, the company started producing fuel-cell systems for a production version of its hydrogen-powered iX5 sport-utility vehicle. Zipse indicated it would be sold in the United States within the next five years, although in a follow-up phone call a spokesperson declined to confirm that point. Bloomberg previously reported that BMW will start delivering fewer than 100 of the iX5 hydrogen vehicles to select partners in Europe, the U.S., and Asia, where Asia leads on hydrogen fuel cells today, from the end of this year.

All told, BMW will eventually offer five different drivetrains to help diversify alternative-fuel options within the group, as hybrids gain renewed momentum in the U.S., Zipse says.

“To say in the U.K. about 2030 or the U.K. and in Europe in 2035, there’s only one drivetrain, that is a dangerous thing,” he says. “For the customers, for the industry, for employment, for the climate, from every angle you look at, that is a dangerous path to go to.” 

Zipse’s hydrogen dreams could even extend to the group’s crown jewel, Rolls-Royce, which BMW has owned since 1998. The “magic carpet ride” driving style that has become Rolls-Royce’s signature selling point is flexible enough to be powered by alternatives to electricity, says Rolls-Royce CEO Torsten Müller-Ötvös. 

“To house, let’s say, fuel cell batteries: Why not? I would not rule that out,” Müller-Ötvös told reporters during a roundtable conversation in Goodwood on the eve of the debut of the company’s first-ever electric vehicle, Spectre. “There is a belief in the group that this is maybe the long-term future.”

Such a vehicle would contain a hydrogen fuel-cell drivetrain combined with BMW’s electric “eDrive” system. It works by converting hydrogen into electricity to reach an electrical output of up to 125 kW/170 horsepower and total system output of nearly 375hp, with water vapor as the only emission, according to the brand.

Hydrogen’s big advantage over electric power, as EVs versus fuel cells debates note, is that it can supply fuel cells stored in carbon-fiber-reinforced plastic tanks. “There will [soon] be markets where you must drive emission-free, but you do not have access to public charging infrastructure,” Zipse says. “You could argue, well you also don’t have access to hydrogen infrastructure, but this is very simple to do: It’s a tank which you put in there like an old [gas] tank, and you recharge it every six months or 12 months.”

Fuel cells at BMW would also help reduce its dependency on raw materials like lithium and cobalt, because the hydrogen-based system uses recyclable components made of aluminum, steel, and platinum. 

Zipse’s continued commitment to prioritizing hydrogen has become an increasingly outlier position in the automotive world. In the last five years, electric-only vehicles have become the dominant alternative fuel — as the age of electric cars dawns ahead of schedule — if not yet on the road, where fewer than 3% of new cars have plugs, at least at car shows and new-car launches.

Rivals Mercedes-Benz and Audi scrapped their own plans to develop fuel cell vehicles and instead have poured tens of billions of dollars into developing pure-electric vehicle, including Daimler's electrification plan initiatives. Porsche went public to finance its own electric aspirations. 

BMW will make half of all new-car sales electric by 2030 across the group, with many expecting most drivers to go electric within a decade, which includes MINI and Rolls-Royce. 
 

 

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