WikiLeaks reveal Alberta power plans

Quinone-mediated fuel cell uses a bio-inspired organic shuttle to carry electrons and protons to a nearby cobalt catalyst, improving hydrogen conversion, cutting platinum dependence, and raising efficiency while lowering costs for clean electricity.

Key Points

An affordable, bio-inspired fuel cell using an organic quinone shuttle and cobalt catalyst to move electrons efficiently

✅ Organic quinone shuttles electrons to a separate cobalt catalyst

✅ Reduces platinum use, lowering cost of hydrogen power

✅ Bio-inspired design aims to boost efficiency and durability

Fuel cells have long been viewed as a promising power source. But most fuel cells are too expensive, inefficient, or both. In a new approach, inspired by biology, a team has designed a fuel cell using cheaper materials and an organic compound that shuttles electrons and protons.

Fuel cells have long been viewed as a promising power source. These devices, invented in the 1830s, generate electricity directly from chemicals, such as hydrogen and oxygen, and produce only water vapor as emissions. But most fuel cells are too expensive, inefficient, or both.

In a new approach, inspired by biology and published today (Oct. 3, 2018) in the journal Joule, a University of Wisconsin-Madison team has designed a fuel cell using cheaper materials and an organic compound that shuttles electrons and protons.

In a traditional fuel cell, the electrons and protons from hydrogen are transported from one electrode to another, where they combine with oxygen to produce water. This process converts chemical energy into electricity. To generate a meaningful amount of charge in a short enough amount of time, a catalyst is needed to accelerate the reactions.

Right now, the best catalyst on the market is platinum -- but it comes with a high price tag, and while advances like low-cost heat-to-electric materials show promise, they address different conversion pathways. This makes fuel cells expensive and is one reason why there are only a few thousand vehicles running on hydrogen fuel currently on U.S. roads.

Shannon Stahl, the UW-Madison professor of chemistry who led the study in collaboration with Thatcher Root, a professor of chemical and biological engineering, says less expensive metals can be used as catalysts in current fuel cells, but only if used in large quantities. "The problem is, when you attach too much of a catalyst to an electrode, the material becomes less effective," he says, "leading to a loss of energy efficiency."

The team's solution was to pack a lower-cost metal, cobalt, into a reactor nearby, where the larger quantity of material doesn't interfere with its performance. The team then devised a strategy to shuttle electrons and protons back and forth from this reactor to the fuel cell.

The right vehicle for this transport proved to be an organic compound, called a quinone, that can carry two electrons and protons at a time. In the team's design, a quinone picks up these particles at the fuel cell electrode, transports them to the nearby reactor filled with an inexpensive cobalt catalyst, and then returns to the fuel cell to pick up more "passengers."

Many quinones degrade into a tar-like substance after only a few round trips. Stahl's lab, however, designed an ultra-stable quinone derivative. By modifying its structure, the team drastically slowed down the deterioration of the quinone. In fact, the compounds they assembled last up to 5,000 hours -- a more than 100-fold increase in lifetime compared to previous quinone structures.

"While it isn't the final solution, our concept introduces a new approach to address the problems in this field," says Stahl. He notes that the energy output of his new design produces about 20 percent of what is possible in hydrogen fuel cells currently on the market. On the other hand, the system is about 100 times more effective than biofuel cells that use related organic shuttles.

The next step for Stahl and his team is to bump up the performance of the quinone mediators, allowing them to shuttle electrons more effectively and produce more power. This advance would allow their design to match the performance of conventional fuel cells, but with a lower price tag.

"The ultimate goal for this project is to give industry carbon-free options for creating electricity, including thermoelectric materials that harvest waste heat," says Colin Anson, a postdoctoral researcher in the Stahl lab and publication co-author. "The objective is to find out what industry needs and create a fuel cell that fills that hole."

This step in the development of a cheaper alternative could eventually be a boon for companies like Amazon and Home Depot that already use hydrogen fuel cells to drive forklifts in their warehouses.

"In spite of major obstacles, the hydrogen economy, with efforts such as storing electricity in pipelines in Europe, seems to be growing," adds Stahl, "one step at a time."

Financial support for this project was provided by the Center for Molecular Electrocatalysis, an Energy Frontier Research Center funded by the U.S. Department of Energy, Office of Science, Office of Basic Energy Sciences, and by the Wisconsin Alumni Research Foundation (WARF) through the WARF Accelerator Program.

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TTC Battery-Electric Buses lead Toronto transit toward zero-emission mobility, improving air quality and climate goals with sustainable operations, advanced charging infrastructure, lower maintenance, energy efficiency, and reliable public transportation across the Toronto Transit Commission network.

Key Points

TTC battery-electric buses are zero-emission vehicles improving quality, lowering costs, and providing efficient service.

✅ Zero tailpipe emissions improve urban air quality

✅ Lower maintenance and energy costs increase savings

✅ Charging infrastructure enables reliable operations

The Toronto Transit Commission (TTC) has embarked on an exciting new chapter in its commitment to sustainability with the introduction of battery-electric buses to its fleet. This strategic move not only highlights the TTC's dedication to reducing its environmental impact but also positions Toronto as a leader in the evolution of public transportation. As cities worldwide strive for greener solutions, the TTC’s initiative stands as a significant milestone toward a more sustainable urban future.

Embracing Green Technology

The decision to integrate battery-electric buses into Toronto's transit system aligns with a growing trend among urban centers to adopt cleaner, more efficient technologies, including Metro Vancouver electric buses now in service. With climate change posing urgent challenges, transit authorities are rethinking their operations to foster cleaner air and reduce greenhouse gas emissions. The TTC’s new fleet of battery-electric buses represents a proactive approach to addressing these concerns, aiming to create a cleaner, healthier environment for all Torontonians.

Battery-electric buses operate without producing tailpipe emissions, and deployments like Edmonton's first electric bus illustrate this shift, offering a stark contrast to traditional diesel-powered vehicles. This transition is crucial for improving air quality in urban areas, where transportation is a leading source of air pollution. By choosing electric options, the TTC not only enhances the city’s air quality but also contributes to the global effort to combat climate change.

Economic and Operational Advantages

Beyond environmental benefits, battery-electric buses present significant economic advantages. Although the initial investment for electric buses may be higher than that for conventional diesel buses, and broader adoption challenges persist, the long-term savings are substantial. Electric buses have lower operating costs due to reduced fuel expenses and less frequent maintenance requirements. The electric propulsion system generally involves fewer moving parts than traditional engines, resulting in lower overall maintenance costs and improved service reliability.

Moreover, the increased efficiency of electric buses translates into reduced energy consumption. Electric buses convert a larger proportion of energy from the grid into motion, minimizing waste and optimizing operational effectiveness. This not only benefits the TTC financially but also enhances the overall experience for riders by providing a more reliable and punctual service.

Infrastructure Development

To support the introduction of battery-electric buses, the TTC is also investing in necessary infrastructure upgrades, including the installation of charging stations throughout the city. These charging facilities are essential for ensuring that the electric fleet can operate smoothly and efficiently. By strategically placing charging stations at transit hubs and along bus routes, the TTC aims to create a seamless transition for both operators and riders.

This infrastructure development is critical not just for the operational capacity of the electric buses but also for fostering public confidence in this new technology, and consistent safety measures such as the TTC's winter safety policy on lithium-ion devices reinforce that trust. As the TTC rolls out these vehicles, clear communication regarding their operational logistics, including charging times and routes, will be essential to inform and engage the community.

Engaging the Community

The TTC is committed to engaging with Toronto’s diverse communities throughout the rollout of its battery-electric bus program. Community outreach initiatives will help educate residents about the benefits of electric transit, addressing any concerns and building public support, and will also discuss emerging alternatives like Mississauga fuel cell buses in the region. Informational campaigns, workshops, and public forums will provide opportunities for dialogue, allowing residents to voice their opinions and learn more about the technology.

This engagement is vital for ensuring that the transition is not just a top-down initiative but a collaborative effort that reflects the needs and interests of the community. By fostering a sense of ownership among residents, the TTC can cultivate support for its sustainable transit goals.

A Vision for the Future

The TTC’s introduction of battery-electric buses marks a transformative moment in Toronto’s public transit landscape. This initiative exemplifies the commission's broader vision of creating a more sustainable, efficient, and user-friendly transportation network. As the city continues to grow, the need for innovative solutions to urban mobility challenges becomes increasingly critical.

By embracing electric technology, the TTC is setting an example for other transit agencies across Canada and beyond, and piloting driverless EV shuttles locally underscores that leadership. This initiative is not just about introducing new vehicles; it is about reimagining public transportation in a way that prioritizes environmental responsibility and community engagement. As Toronto moves forward, the integration of battery-electric buses will play a crucial role in shaping a cleaner, greener future for urban transit, ultimately benefitting residents and the planet alike.

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Fukushima Daiichi decommissioning delay highlights TEPCO's revised timeline, spent fuel removal at Units 1 and 2, safety enclosures, decontamination, fuel debris extraction by robot arm, and contaminated water management under stricter radiation control.

Key Points

A government revised schedule pushing back spent fuel removal and decommissioning milestones at Fukushima Daiichi.

✅ TEPCO delays spent fuel removal at Units 1 and 2 for safety.

✅ Enclosures, decontamination, and robotics mitigate radioactive risk.

✅ Contaminated water cut target: 170 tons/day to 100 by 2025.

The Japanese government decided Friday to delay the removal of spent fuel from the Fukushima Daiichi nuclear power plant's Nos. 1 and 2 reactors by as much as five years, casting doubt on whether it can stick to its timeframe for dismantling the crippled complex.

The process of removing the spent fuel from the units' pools had previously been scheduled to begin in the year through March 2024.

In its latest decommissioning plan, the government said the plant's operator, Tokyo Electric Power Company Holdings Inc., will not begin the roughly two-year process (a timeline comparable to major reactor refurbishment programs seen worldwide) at the No. 1 unit at least until the year through March 2028 and may wait until the year through March 2029.

Work at the No. 2 unit is now slated to start between the year through March 2025 and the year through March 2027, it said.

The delay is necessary to take further safety precautions such as the construction of an enclosure around the No. 1 unit to prevent the spread of radioactive dust, and decontamination of the No. 2 unit, even as authorities have begun reopening previously off-limits towns nearby, the government said. It is the fourth time it has revised its schedule for removing the spent fuel rods.

"It's a very difficult process and it's hard to know what to expect. The most important thing is the safety of the workers and the surrounding area," industry minister Hiroshi Kajiyama told a press conference.

The government set a new goal of finishing the removal of the 4,741 spent fuel rods across all six of the plant's reactors by the year through March 2032, amid ongoing debates about the consequences of early nuclear plant closures elsewhere.

Plant operator TEPCO has started the process at the No. 3 unit and already finished at the No. 4 unit, which was off-line for regular maintenance at the time of the disaster. A schedule has yet to be set for the Nos. 5 and 6 reactors.

While the government maintained its overarching timeframe of finishing the decommissioning of the plant 30 to 40 years from the 2011 crisis triggered by a magnitude 9.0 earthquake and tsunami, there may be further delays, even as milestones at other nuclear projects are being reached worldwide.

The government said it will begin removing fuel debris from the three reactors that experienced core meltdowns in the year through March 2022, starting with the No. 2 unit as part of broader reactor decommissioning efforts.

The process, considered the most difficult part of the decommissioning plan, will involve using a robot arm, reflecting progress in advanced reactors technologies, to initially remove small amounts of debris, moving up to larger amounts.

The government also said it will aim to reduce the pace at which contaminated water at the plant increases. Water for cooling the melted cores, mixed with underground water, amounts to around 170 tons a day. That number will be brought down to 100 tons by 2025, it said.

The water is being treated to remove the most radioactive materials and stored in tanks on the plant's grounds, but already more than 1 million tons has been collected and space is expected to run out by the summer of 2022.

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Texas Gulf Coast Power Outages from Harvey continue as flooding, high winds, and downed lines paralyze Houston and coastal utilities, while restoration crews from out-of-state work to repair infrastructure and restore electricity across impacted communities.

Key Points

Power disruptions across Houston and the Gulf Coast from Harvey, driven by flooding, wind damage, and blocked access.

✅ CenterPoint warns multi-day outages in flooded zones.

✅ AEP Texas aided by crews from Kentucky, Illinois, Missouri.

✅ Entergy expects more outages as storm nears Galveston.

Hundreds of thousands of Texans were without power along the Gulf Coast as Tropical Storm Harvey left parts of the Houston area under water, with extended Houston outages compounding response efforts.

There were roughly 280,000 customers without power along the Texas's coast and in Houston and the surrounding areas on Monday, according to reported outages by the state's investor-owned utilities. Harvey, which made landfall on Friday, caused devastating flooding and knocked out power lines along its destructive path, similar to the Louisiana grid rebuild after Laura that required weeks of restoration.

CenterPoint Energy reported more than 100,000 outages earlier on Monday, though that figure was down to 91,744 shortly after 1 p.m. on Monday.

The company said it was unable to access hard-hit areas until floodwaters recede and electric infrastructure dries out, a challenge that, as seen in Florida power restoration efforts elsewhere, has taken weeks to resolve. Outages in the most flooded areas could last for several days, CenterPoint warned.

AEP Texas's coverage area south of Houston had 150,500 customers without electricity as of 11 a.m. ET on Monday. That was down from the peak of its outages on Saturday afternoon, which affected 220,000 customers.

Former FEMA deputy director: Texas has already begun recovery from storm  1:54 PM ET Mon, 28 Aug 2017 | 05:57

Corpus Christi and the surrounding areas along the Gulf Coast were still experiencing the most outages, while persistent Toronto outages after a spring storm underscored how long recovery can take in urban areas. AEP credited assistance from out-of-state workers for helping to get the lights back on.

"Thousands of resources have arrived from across the country to help AEP Texas with restoration efforts following this historic weather event. Crews from Kentucky, Illinois, Missouri and other states have arrived and are working on restoring power to those impacted by Hurricane Harvey," AEP said in a statement.

Entergy reported 29,500 customers were without power on Monday in areas north of Houston. The company warned that additional outages were expected if Harvey moves inland near the island city of Galveston on Wednesday as anticipated, a pattern similar to New Orleans during Ida where electricity failed despite levees holding.

Houston, Beaumont and Victoria are expected to see continued periods of torrential rain through Tuesday, before Harvey begins to move north on Wednesday and out of the flood zone by Thursday.

"Our crews are safely restoring power as quickly as possible, but the continued wind, rain and flooding are having an impact on restoration efforts," Entergy said in a statement.

South of Houston, about 7,500 Texas New Mexico Power Company customers were still experiencing outages, according to the company's outage map.

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Offshore wind power accelerates low-carbon electrification, leveraging floating turbines, high capacity factors, HVDC transmission, and hydrogen production to decarbonize grids, cut CO2, and deliver competitive, reliable renewable energy near demand centers.

Key Points

Offshore wind power uses offshore turbines to deliver low-carbon electricity with high capacity factors and falling costs.

✅ Sea-based wind farms with 40-50% capacity factors

✅ Floating turbines unlock deep-water, far-shore resources

✅ Enables hydrogen production and strengthens grid reliability

The need for affordable low-carbon technologies is greater than ever

Global energy-related CO2 emissions reached a historic high in 2018, driven by an increase in coal use in the power sector. Despite impressive gains for renewables, fossil fuels still account for nearly two-thirds of electricity generation, the same share as 20 years ago. There are signs of a shift, with increasing pledges to decarbonise economies and tackle air pollution, and with World Bank support helping developing countries scale wind, but action needs to accelerate to meet sustainable energy goals. As electrification of the global energy system continues, the need for clean and affordable low-carbon technologies to produce this electricity is more pressing than ever. This World Energy Outlook special report offers a deep dive on a technology that today has a total capacity of 23 GW (80% of it in Europe) and accounts for only 0.3% of global electricity generation, but has the potential to become a mainstay of the world's power supply. The report provides the most comprehensive analysis to date of the global outlook for offshore wind, its contributions to electricity systems and its role in clean energy transitions.

The offshore wind market has been gaining momentum

The global offshore wind market grew nearly 30% per year between 2010 and 2018, benefitting from rapid technology improvements. Over the next five years, about 150 new offshore wind projects are scheduled to be completed around the world, pointing to an increasing role for offshore wind in power supplies. Europe has fostered the technology's development, led by the UK offshore wind sector alongside Germany and Denmark. The United Kingdom and Germany currently have the largest offshore wind capacity in operation, while Denmark produced 15% of its electricity from offshore wind in 2018. China added more capacity than any other country in 2018.

The untapped potential of offshore wind is vast

The best offshore wind sites could supply more than the total amount of electricity consumed worldwide today. And that would involve tapping only the sites close to shores. The IEA initiated a new geospatial analysis for this report to assess offshore wind technical potential country by country. The analysis was based on the latest global weather data on wind speed and quality while factoring in the newest turbine designs. Offshore wind's technical potential is 36 000 TWh per year for installations in water less than 60 metres deep and within 60 km from shore. Global electricity demand is currently 23 000 TWh. Moving further from shore and into deeper waters, floating turbines could unlock enough potential to meet the world's total electricity demand 11 times over in 2040. Our new geospatial analysis indicates that offshore wind alone could meet several times electricity demand in a number of countries, including in Europe, the United States and Japan. The industry is adapting various floating foundation technologies that have already been proven in the oil and gas sector. The first projects are under development and look to prove the feasibility and cost-effectiveness of floating offshore wind technologies.

Offshore wind's attributes are very promising for power systems

New offshore wind projects have capacity factors of 40-50%, as larger turbines and other technology improvements are helping to make the most of available wind resources. At these levels, offshore wind matches the capacity factors of gas- and coal-fired power plants in some regions – though offshore wind is not available at all times. Its capacity factors exceed those of onshore wind and are about double those of solar PV. Offshore wind output varies according to the strength of the wind, but its hourly variability is lower than that of solar PV. Offshore wind typically fluctuates within a narrower band, up to 20% from hour to hour, than solar PV, which varies up to 40%.

Offshore wind's high capacity factors and lower variability make its system value comparable to baseload technologies, placing it in a category of its own – a variable baseload technology. Offshore wind can generate electricity during all hours of the day and tends to produce more electricity in winter months in Europe, the United States and China, as well as during the monsoon season in India. These characteristics mean that offshore wind's system value is generally higher than that of its onshore counterpart and more stable over time than that of solar PV. Offshore wind also contributes to electricity security, with its high availability and seasonality patterns it is able to make a stronger contribution to system needs than other variable renewables. In doing so, offshore wind contributes to reducing CO2 and air pollutant emissions while also lowering the need for investment in dispatchable power plants. Offshore wind also has the advantage of avoiding many land use and social acceptance issues that other variable renewables are facing.

Offshore wind is on track to be a competitive source of electricity

Offshore wind is set to be competitive with fossil fuels within the next decade, as well as with other renewables including solar PV. The cost of offshore wind is declining and is set to fall further. Financing costs account for 35% to 50% of overall generation cost, and supportive policy frameworks are now enabling projects to secure low cost financing in Europe, with zero-subsidy tenders being awarded. Technology costs are also falling. The levelised cost of electricity produced by offshore wind is projected to decline by nearly 60% by 2040. Combined with its relatively high value to the system, this will make offshore wind one of the most competitive sources of electricity. In Europe, recent auctions indicate that offshore wind will soon beat new natural gas-fired capacity on cost and be on a par with solar PV and onshore wind. In China, offshore wind is set to become competitive with new coal-fired capacity around 2030 and be on par with solar PV and onshore wind. In the United States, recent project proposals indicate that offshore wind will soon be an affordable option, even as the 1 GW timeline continues to evolve, with potential to serve demand centres along the country's east coast.

Innovation is delivering deep cost reductions in offshore wind, and transmission costs will become increasingly important. The average upfront cost to build a 1 gigawatt offshore wind project, including transmission, was over $4 billion in 2018, but the cost is set to drop by more than 40% over the next decade. This overall decline is driven by a 60% reduction in the costs of turbines, foundations and their installation. Transmission accounts for around one-quarter of total offshore wind costs today, but its share in total costs is set to increase to about one-half as new projects move further from shore. Innovation in transmission, for example through work to expand the limits of direct current technologies, will be essential to support new projects without raising their overall costs.

Offshore wind is set to become a $1 trillion business

Offshore wind power capacity is set to increase by at least 15-fold worldwide by 2040, becoming a $1 trillion business. Under current investment plans and policies, the global offshore wind market is set to expand by 13% per year, reflecting its growth despite Covid-19 in recent years, passing 20 GW of additions per year by 2030. This will require capital spending of $840 billion over the next two decades, almost matching that for natural gas-fired or coal-fired capacity. Achieving global climate and sustainability goals would require faster growth: capacity additions would need to approach 40 GW per year in the 2030s, pushing cumulative investment to over $1.2 trillion. 

The promising outlook for offshore wind is underpinned by policy support in an increasing number of regions. Several European North Seas countries – including the United Kingdom, Germany, the Netherlands and Denmark – have policy targets supporting offshore wind. Although a relative newcomer to the technology, China is quickly building up its offshore wind industry, aiming to develop a project pipeline of 10 GW by 2020. In the United States, state-level targets and federal incentives are set to kick-start the U.S. offshore wind surge in the coming years. Additionally, policy targets are in place and projects under development in Korea, Japan, Chinese Taipei and Viet Nam.

 The synergies between offshore wind and offshore oil and gas activities provide new market opportunities. Since offshore energy operations share technologies and elements of their supply chains, oil and gas companies started investing in offshore wind projects many years ago. We estimate that about 40% of the full lifetime costs of an offshore wind project, including construction and maintenance, have significant synergies with the offshore oil and gas sector. That translates into a market opportunity of $400 billion or more in Europe and China over the next two decades. The construction of foundations and subsea structures offers potential crossover business, as do practices related to the maintenance and inspection of platforms. In addition to these opportunities, offshore oil and gas platforms require electricity that is often supplied by gas turbines or diesel engines, but that could be provided by nearby wind farms, thereby reducing CO2 emissions, air pollutants and costs.

Offshore wind can accelerate clean energy transitions

Offshore wind can help drive energy transitions by decarbonising electricity and by producing low-carbon fuels. Over the next two decades, its expansion could avoid between 5 billion and 7 billion tonnes of CO2 emissions from the power sector globally, while also reducing air pollution and enhancing energy security by reducing reliance on imported fuels. The European Union is poised to continue leading the wind energy at sea in Europe industry in support of its climate goals: its offshore wind capacity is set to increase by at least fourfold by 2030. This growth puts offshore wind on track to become the European Union's largest source of electricity in the 2040s. Beyond electricity, offshore wind's high capacity factors and falling costs makes it a good match to produce low-carbon hydrogen, a versatile product that could help decarbonise the buildings sector and some of the hardest to abate activities in industry and transport. For example, a 1 gigawatt offshore wind project could produce enough low-carbon hydrogen to heat about 250 000 homes. Rising demand for low-carbon hydrogen could also dramatically increase the market potential for offshore wind. Europe is looking to develop offshore "hubs" for producing electricity and clean hydrogen from offshore wind.

It's not all smooth sailing

Offshore wind faces several challenges that could slow its growth in established and emerging markets, but policy makers and regulators can clear the path ahead. Developing efficient supply chains is crucial for the offshore wind industry to deliver low-cost projects. Doing so is likely to call for multibillion-dollar investments in ever-larger support vessels and construction equipment. Such investment is especially difficult in the face of uncertainty. Governments can facilitate investment of this kind by establishing a long-term vision for offshore wind and by drawing on U.K. policy lessons to define the measures to be taken to help make that vision a reality. Long-term clarity would also enable effective system integration of offshore wind, including system planning to ensure reliability during periods of low wind availability.

The success of offshore wind depends on developing onshore grid infrastructure. Whether the responsibility for developing offshore transmission lies with project developers or transmission system operators, regulations should encourage efficient planning and design practices that support the long-term vision for offshore wind. Those regulations should recognise that the development of onshore grid infrastructure is essential to the efficient integration of power production from offshore wind. Without appropriate grid reinforcements and expansion, there is a risk of large amounts of offshore wind power going unused, and opportunities for further expansion could be stifled. Development could also be slowed by marine planning practices, regulations for awarding development rights and public acceptance issues.

The future of offshore wind looks bright but hinges on the right policies

The outlook for offshore wind is very positive as efforts to decarbonise and reduce local pollution accelerate. While offshore wind provides just 0.3% of global electricity supply today, it has vast potential around the world and an important role to play in the broader energy system. Offshore wind can drive down CO2 emissions and air pollutants from electricity generation. It can also do so in other sectors through the production of clean hydrogen and related fuels. The high system value of offshore wind offers advantages that make a strong case for its role alongside other renewables and low-carbon technologies. Government policies will continue to play a critical role in the future of offshore wind and  the overall pace of clean energy transitions around the world.

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U.S. Climate Change Donation Survey reveals Americans' willingness to fund sustainability via government incentives, electrification, and renewable energy. Public opinion favors wind, solar, and decarbonization, highlighting policy support post-pandemic amid economic recovery efforts.

Key Points

A 2020 U.S. poll on climate attitudes: donation willingness, renewable support, and views on government incentives.

✅ 70% would donate income; 31% would donate nothing.

✅ 59% prefer government incentives; 47% support taxes, conservation.

✅ 85% land wind, 83% offshore wind, 90% solar support.

A new study of American consumers' attitudes toward climate change finds that more than two-thirds of respondents (70%) indicate their willingness to give or donate a percentage of their personal income to support the fight against climate change and the path to net-zero electricity emissions by mid-century. 

Twenty-eight percent indicated they were willing to provide less than 1% of their income; 33% said they would be willing to contribute 1-5% of their income; 6% said they would give between 6-10% of their income; and 3% indicated they would contribute more than 10% of their income. Just under one-third (31%) of those surveyed indicated they were unwilling to give or donate any percentage of their income to support the fight against climate change.

The U.S. findings are part of a series of surveys commissioned by Nexans in the U.S., UK and France, in order to determine public opinion on climate change and related issues in the wake of the COVID-19 pandemic. The U.S. study was conducted online by Researchscape from August 20 – 24, 2020. It had 1,013 respondents, ages 18 or older, with the results weighted to be representative of the overall population (variables available upon request).

Nexans, is headquartered in Paris with a major offshore wind cable manufacturing facility in Charleston, S.C. and an industrial cable manufacturing facility in El Dorado, Ark. The company is fully committed to fighting climate change and is helping to make sustainable electrification possible. The survey was developed as part of its celebration of the first Climate Day in Paris which included a roundtable event with world-renowned experts, the release of an unprecedented global study by Roland Berger on the challenges raised by the electrification of the world, the question of whether the global energy transition is on track, and Nexans' own commitment to be carbon neutral by 2030.

Paying the Tab to Address Climate Change

Participants were given the opportunity to choose from seven multiple responses to the question "How should the fight against climate change be paid for?" The majority (59%) replied it should be paid for by "government incentives for both businesses and consumers." It was followed by "federal, state and/or local taxes" and "conservation programs" (tied at 47%); "business investments" (42%), such as carbon-free electricity initiatives, and "consumer-driven purchases" (33%). Just 9% selected none of the above and 2% selected other.

"Through the organization of this Climate Day, Nexans is asserting itself not only as an actor but also a thought leader of the energy transition for a sustainable electrification of the world. This electrification raises a number of challenges and paradoxes that must be overcome. And it will only happen with the direct involvement of the populations concerned. These surveys provide a better understanding of the level of information and disinformation, including climate change denial, in public opinion as well as their level of acceptability of these lifestyle changes," said Christopher Guérin, CEO, Nexans.

Among other findings, 44% are dissatisfied with the job that federal and state governments are doing to address climate change, while utilities like Duke Energy face investor pressure to release climate reports, 35% are somewhat satisfied and 21% are either very satisfied or completed satisfied with government's role.

Americans expressed overwhelmingly favorable views of wind and solar renewable energy proposals, as carbon emissions fall when electricity producers move away from coal. Specifically, 85% stated being in favor of wind turbines on land (15% against), 83% in favor of wind turbines off the coast (17% against) and 90% in support of solar panel farms (10% opposed).

Those surveyed were asked about their current and changing priorities towards climate change as influenced by the coronavirus pandemic and impacts like extreme heat on electricity bills. Thirty-nine percent indicated that climate change was no more and no less a priority due to the current health emergency; just under a third (31%) indicated that climate change is more of a priority while 30% said it was less of a priority.

In similar research conducted by Nexans in the United Kingdom, nearly two thirds (65.8%) of UK respondents said they would be willing to donate part of their salary to fight climate change. Furthermore, nearly a third (29%) of the UK's consumers believe that combating climate change has become more of a priority in light of the coronavirus pandemic. The UK research was conducted online by Savanta from August 21 – 24, 2020. A total of 2210 respondents, aged 16 and above, representative of the UK population took part.

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