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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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Rising Greenhouse Gas Concentrations drive climate change, with CO2, methane, and nitrous oxide surging; WMO data show higher radiative forcing, elevated pre-industrial baselines, and persistent atmospheric concentrations despite Paris Agreement emissions pledges.

Key Points

Increasing atmospheric CO2, methane, and nitrous oxide levels that raise radiative forcing and drive warming.

✅ WMO data show CO2 at 407.8 ppm in 2018, above decade average

✅ Methane and nitrous oxide surged, elevating total radiative forcing

✅ Concentrations differ from emissions; sinks absorb about half

The World Meteorological Organization (WMO) says the increase in CO2 was just above the average rise recorded over the last decade.

Levels of other warming gases, such as methane and nitrous oxide, have also surged by above average amounts.

Since 1990 there's been an increase of 43% in the warming effect on the climate of long lived greenhouse gases.

The WMO report looks at concentrations of warming gases in the atmosphere rather than just emissions.

The difference between the two is that emissions refer to the amount of gases that go up into the atmosphere from the use of fossil fuels, such as burning coal for coal-fired electricity generation and from deforestation.

Concentrations are what's left in the air after a complex series of interactions between the atmosphere, the oceans, the forests and the land. About a quarter of all carbon emissions are absorbed by the seas, and a similar amount by land and trees, while technologies like carbon capture are being explored to remove CO2.

Using data from monitoring stations in the Arctic and all over the world, researchers say that in 2018 concentrations of CO2 reached 407.8 parts per million (ppm), up from 405.5ppm a year previously.

This increase was above the average for the last 10 years and is 147% of the "pre-industrial" level in 1750.

The WMO also records concentrations of other warming gases, including methane and nitrous oxide, and some countries have reported declines in certain potent gases, as noted in US greenhouse gas controls reports, though global levels remain elevated. About 40% of the methane emitted into the air comes from natural sources, such as wetlands, with 60% from human activities, including cattle farming, rice cultivation and landfill dumps.

Methane is now at 259% of the pre-industrial level and the increase seen over the past year was higher than both the previous annual rate and the average over the past 10 years.

Nitrous oxide is emitted from natural and human sources, including from the oceans and from fertiliser-use in farming. According to the WMO, it is now at 123% of the levels that existed in 1750.

Last year's increase in concentrations of the gas, which can also harm the ozone layer, was bigger than the previous 12 months and higher than the average of the past decade.

What concerns scientists is the overall warming impact of all these increasing concentrations. Known as total radiative forcing, this effect has increased by 43% since 1990, and is not showing any indication of stopping.

There is no sign of a slowdown, let alone a decline, in greenhouse gases concentration in the atmosphere despite all the commitments under the Paris agreement on climate change and the ongoing global energy transition efforts," said WMO Secretary-General Petteri Taalas.

"We need to translate the commitments into action and increase the level of ambition for the sake of the future welfare of mankind," he added.

"It is worth recalling that the last time the Earth experienced a comparable concentration of CO2 was three to five million years ago. Back then, the temperature was 2-3C warmer, sea level was 10-20m higher than now," said Mr Taalas.

The UN Environment Programme will report shortly on the gap between what actions countries are taking to cut carbon, for example where Australia's emissions rose 2% recently, and what needs to be done to keep under the temperature targets agreed in the Paris climate pact.

Preliminary findings from this study, published during the UN Secretary General's special climate summit last September, indicated that emissions continued to rise during 2018, although global emissions flatlined in 2019 according to the IEA.

Both reports will help inform delegates from almost 200 countries who will meet in Madrid next week for COP25, following COP24 in Katowice the previous year, the annual round of international climate talks.

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2019 Grid Edge Trends highlight evolving demand response, DER orchestration, real-time operations, AMI data, and EV charging, as wholesale markets seek flexibility and resiliency amid tighter reserve margins and fossil baseload retirements.

Key Points

Shifts toward DER-enabled demand response and real-time, behind-the-meter flexibility.

✅ Real-time DER dispatch enhances reliability during tight reserves

✅ AMI and ICT improve forecasting, monitoring, and control of resources

✅ Demand response shifts toward aggregated behind-the-meter orchestration

Which grid edge trends will continue into 2019 as the digital grid matures and what kind of disruption is on the horizon in the coming year?

From advanced metering infrastructure endpoints to electric-vehicle chargers, grid edge venture capital investments to demand response events, hundreds of data points go into tracking new trends at the edge of the grid amid ongoing grid modernization discussions across utilities.

Trends across these variables tell a story of transition, but perhaps not yet transformation. Customers hold more power than ever before in 2019, with utilities and vendors innovating to take advantage of new opportunities behind the meter. Meanwhile, external factors can always throw things off-course, including the data center boom that is posing new power challenges, and reliability is top of mind in light of last year's extreme weather events. What does the 2018 data say about 2019?

For one thing, demand response evolved, enabled by new information and communications technology. Last year, wholesale market operators increasingly sought to leverage the dispatch of distributed energy resource flexibility in close to real time. Three independent system operators and regional transmission organizations called on demand response five times in total for relief in the summer of 2018, including the NYISO.

The demand response events called in the last 18 months send a clear message: Grid operators will continue to call events year-round. This story unfolds as reserve margins continue to tighten, fossil baseload generation retirements continue, and system operators are increasingly faced with proving the resiliency and reliability of their systems while efforts to invest in a smarter electricity infrastructure gain momentum across the country.

In 2019, the total amount of flexible demand response capacity for wholesale market participation will remain about the same. However, the way operators and aggregators are using demand response is changing as information and communications technology systems improve and utilities are using AI to adapt to electricity demands, allowing the behavior of resources to be more accurately forecasted, monitored and controlled.

These improvements are allowing customer-sited resources to offer  flexibility services closer to real-time operations and become more reactive to system needs. At the same time, traditional demand response will continue to evolve toward the orchestration of DERs as an aggregate flexible resource to better enable growing levels of renewable energy on the grid.

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BC Hydro Review Phase 2 Recommendations advance affordable electricity rates, clean energy adoption, electrification, and demand response, supporting heat pumps, EV charging, and low-income programs to cut emissions and meet CleanBC climate targets.

Key Points

Policies to keep rates affordable and accelerate clean electrification via heat pump, EV, and demand response incentives.

✅ Optional rates, heat pump and EV charging incentives

✅ Demand response via controllable devices lowers peak loads

✅ Expanded support for lower-income customers and affordability

The Province and BC Hydro have released recommendations from Phase 2 of the BC Hydro Review to keep rates affordable, including through a provincial rate freeze initiative that supported households, and encourage greater use of clean, renewable electricity to reduce emissions and achieve climate targets.

“Keeping life affordable for people is a key priority of our government,” said Bruce Ralston, Minister of Energy, Mines and Low Carbon Innovation. “Affordable electricity rates not only help British Columbians, they help ensure the price of electricity remains competitive with other forms of energy, supporting the transition away from fossil fuels to clean electricity in our homes and buildings, vehicles and businesses.”

While affordable rates have always been important to BC Hydro customers, amid proposals such as a modest rate increase under review, expectations are also changing as customers look to have more choice and control over their electricity use and opportunities to save money.

Guided by input from a panel of external energy industry experts, government and BC Hydro have developed recommendations under Phase 2 of the BC Hydro Review to reduce electricity costs for individuals and businesses, even as a 3.75% increase has been discussed, as envisioned by the CleanBC climate strategy. This is also in alignment with TogetherBC, the Province’s poverty reduction strategy, and its guiding principle of affordability.

“As we promote increased use of electricity in B.C. to achieve our climate targets, we need to continue to focus on keeping electricity rates affordable, especially for lower-income families,” said Nicholas Simons, Minister of Social Development and Poverty Reduction. “Through the BC Hydro Review, and continuing engagement with stakeholders and organizations to follow, we are committed to finding ways to keep rates affordable, so everyone has access to the benefits of B.C.’s clean, reliable electricity.”

Recommendations include having BC Hydro consider providing more support for lower-income BC Hydro customers, informed by a recent surplus report that highlighted funding opportunities. These include incentives and exploring optional rates for customers to adopt electric heat pumps, and facilitating customer adoption of controllable energy devices that provide BC Hydro the ability to offer incentives in return for helping to manage a customer’s electricity use. 

Electrification of B.C.’s economy helps customers reduce their carbon footprint and supports the Province’s CleanBC climate strategy, and is an important part of keeping electricity affordable even amid higher BC Hydro rates in recent periods. As more customers make the switch from fossil fuels to using clean electricity in their homes, vehicles and businesses, BC Hydro’s electricity sales will increase, providing more revenue that helps keep rates affordable for everyone.

“We’re making the transition to a cleaner future more affordable for people and businesses across British Columbia through our CleanBC plan,” said George Heyman, Minister of Environment and Climate Change Strategy. “By working with BC Hydro and other partners, we’re making sure everyone has access to clean, affordable electricity to power technologies like high-efficiency heat pumps and electric vehicles that will reduce harmful pollution and improve our homes, buildings and communities.”

Chris O’Riley, president and CEO, BC Hydro, said: “Given the impact of COVID-19 on British Columbians, affordability is more important than ever. That’s why we are committed to continuing to keep rates affordable and offering customers more options that allow them to save on their bills while using clean electricity.”

In July 2021, the Province announced a first set of recommendations from Phase 2 of the BC Hydro Review amid a 3% rate increase approved by regulators. The next announcement from Phase 2 will include recommendations to increase the number of electric vehicles on the road.

In addition, as part of the Draft Action Plan to advance the Declaration on the Rights of Indigenous Peoples Act, the Province is proposing to engage with Indigenous peoples to identify and support new clean energy opportunities related to CleanBC, the BC Hydro Review and the British Columbia Utilities Commission Indigenous Utilities Regulation Inquiry, and to consider lessons from Ontario's hydro policy experiences as appropriate.

B.C. is the cleanest electricity-generation jurisdiction in western North America, with an average of 98% of its electricity generation coming from clean or renewable resources.

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BCER Renewable Energy Permitting streamlines single-window approvals for wind, solar, and transmission projects in BC, cutting red tape, aligning with CleanBC, and accelerating investment, Indigenous partnerships, and low-carbon infrastructure growth provincewide.

Key Points

BC's single-window framework consolidates approvals for wind, solar, and transmission to accelerate energy projects.

✅ Single-window permits via BC Energy Regulator (BCER)

✅ Covers wind, solar, and high-voltage transmission lines

✅ Aligns with CleanBC, supports Indigenous partnerships

In a decisive move to bolster clean energy initiatives, the government of British Columbia (B.C.) has announced plans to overhaul the regulatory framework governing renewable energy projects. This initiative aims to expedite the development of wind, solar, and other renewable energy sources, positioning B.C. as a leader in sustainable energy production.

Transitioning Regulatory Authority to the BC Energy Regulator (BCER)

Central to this strategy is the proposed legislation, set to be introduced in spring 2025, which will transfer the permitting and regulatory oversight of renewable energy projects, aligning with offshore wind regulation plans at the federal level, from multiple agencies to the BC Energy Regulator (BCER). This transition is designed to create a "single-window" permitting process, simplifying approvals and reducing bureaucratic delays for developers.

Expanding BCER's Mandate

Historically known as the British Columbia Oil and Gas Commission, the BCER's mandate has evolved to encompass a broader range of energy projects. The upcoming legislation will empower the BCER to oversee renewable energy projects, including wind and solar, as well as high-voltage transmission lines like the North Coast Transmission Line (NCTL), in step with renewable transmission planning efforts elsewhere in North America. This expansion aims to streamline the regulatory process, providing developers with a single point of contact throughout the project lifecycle.

Economic and Environmental Implications

The restructuring is expected to unlock significant economic opportunities. Projections suggest that the streamlined process could attract between $5 billion and $6 billion in private investment and complement recent federal grid modernization funding initiatives, generating employment opportunities and fostering economic growth. Moreover, by facilitating the rapid deployment of renewable energy projects, B.C. aims to enhance its clean energy capacity, contributing to global sustainability goals.

Strengthening Partnerships with Indigenous Communities

A pivotal aspect of this initiative is the emphasis on collaboration with Indigenous communities. The government has highlighted the importance of engaging First Nations in the development process, ensuring that projects are not only environmentally sustainable but also socially responsible. This approach seeks to honor Indigenous rights and knowledge, fostering partnerships that benefit all stakeholders.

Supporting Infrastructure Development

The acceleration of renewable energy projects necessitates corresponding infrastructure enhancements. The NCTL, for instance, is crucial for meeting the increased electricity demand from sectors such as mining, port electrification, and hydrogen production, and for addressing regional grid constraints that limit renewable integration. By improving the transmission infrastructure, B.C. aims to support the growing energy needs of these industries while promoting clean energy solutions.

Aligning with CleanBC Objectives

This regulatory overhaul aligns seamlessly with B.C.'s CleanBC initiative, which sets ambitious targets for reducing greenhouse gas emissions and promoting energy efficiency, and supports Canada's goal of zero-emissions electricity by 2035 under active consideration. By removing regulatory barriers and expediting project approvals, the government aims to accelerate the transition to a low-carbon economy, positioning B.C. as a hub for clean energy innovation.

Addressing Potential Challenges

While the initiative has been lauded for its potential, experts caution that careful consideration must be given to environmental assessments and Indigenous consultation processes, as well as to lessons from Alberta's solar expansion challenges on land use and grid impacts. Ensuring that projects meet environmental standards and respect Indigenous rights is crucial for the long-term success and acceptance of renewable energy developments.

The proposed changes mark a significant shift in B.C.'s approach to energy development, reflecting a commitment to sustainability and economic growth. As the legislation moves through the legislative process, stakeholders across the energy sector are closely monitoring developments, particularly as Alberta ends its renewables moratorium and resumes project approvals across the Prairies, anticipating a more efficient and transparent regulatory environment that supports the rapid expansion of renewable energy projects.

B.C.'s plan to streamline the regulatory process for clean energy projects represents a bold step toward a sustainable and prosperous energy future. By consolidating regulatory authority under the BCER, fostering Indigenous partnerships, and aligning with broader environmental objectives, the province is setting a precedent for effective governance in the transition to renewable energy.

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CPUC Exit Fee Increase for CCAs adjusts the PCIA, affecting utilities, San Diego ratepayers, renewable energy procurement, customer equity, and cost allocation, while providing regulatory certainty for Community Choice Aggregation programs and clean energy goals.

Key Points

A CPUC-approved change raising PCIA exit fees paid by CCAs to utilities, balancing cost shifts and customer equity.

✅ PCIA rises from about 2.5c to roughly 4.25c per kWh in San Diego

✅ Aims to reduce cost shifts and protect non-CCA customers

✅ Offers regulatory certainty for CCA launches and clean energy goals

The California Public Utilities Commission approved an increase on the exit fees charged to customers who take part in Community Choice Aggregation -- government-run alternatives to traditional utilities like San Diego Gas & Electric.

After reviewing two competing exit fee proposals, all five commissioners voted Thursday in favor of an adjustment that many CCA advocates predicted could hamper the growth of the community choice movement.

But minutes after the vote was announced, one of the leading voices in favor of the city San Diego establishing its own CCA said the decision was good news because it provides some regulatory certainty.

"For us in San Diego, it's a green light to move forward with community choice," said Nicole Capretz, executive director of the Climate Action Campaign. "For us, it's let's go, let's launch and let's give families a choice. We no longer have to wait."

Under the CCA model, utilities still maintain transmission and distribution lines (poles and wires, etc.) and handle customer billing. But officials in a given local government entity make the final decisions about what kind of power sources are purchased.

Once a CCA is formed, its customers must pay an exit fee -- called a Power Charge Indifference Adjustment -- to the legacy utility serving that particular region. The fee is included in customers' monthly bills.

The fee is required to offset the costs of the investments utilities made over the years for things like natural gas power plants, renewable energy facilities and other infrastructure.

Utilities argue if the exit fee is set too low, it does not fairly compensate them for their investments; if it's too high, CCAs complain it reduces the financial incentive for their potential customers.

The Public Utilities Commission chose to adopt a proposal that some said was more favorable to utilities, leading to complaints from CCA boosters.

"We see this will really throw sand in the gears in our ability to do things that can move us toward (climate change) goals," Jim Parks, staff member of Valley Clean Energy, a CCA based in Davis, said before the vote.

Commissioner Carla Peterman, who authored the proposal that passed, said she supports CCAs but stressed the commission has a "legal obligation" to make sure increased costs are not shouldered by "customers who do not, or cannot, join a CCA. Today's proposal ensures a more level playing field between customers."

As for what the vote means for the exit fee in San Diego, Peterman's office earlier in the week estimated the charge would rise from 2.5 cents a kilowatt-hour to about 4.25 cents.

The Clear the Air Coaltion, a San Diego County group critical of CCAs, said the newly established exit fee -- which goes into effect starting next year -- is "a step in the direction."

But the group, which includes the San Diego Regional Chamber of Commerce, the San Diego County Taxpayers Association and lobbyists for Sempra Energy (the parent company of SDG&E), repeated concerns it has brought up before.

"If the city of San Diego decides to get into the energy business this decision means ratepayers in National City, Chula Vista, Carlsbad, Imperial Beach, La Mesa, El Cajon and all other neighboring communities would see higher energy bills, and San Diego taxpayers would be faced with mounting debt," coalition spokesman Tony Manolatos said in an email.

CCA supporters say community choice is critical in ensuring San Diego meets the pledge made by Mayor Kevin Faulconer to adopt the city's Climate Action Plan, mandating 100 percent of the city's electricity needs must come from renewable sources by 2035.

Now attention turns to Faulconer, who promised to make a decision on bringing a CCA proposal to the San Diego City Council only after the utilities commission made its decision.

A Faulconer spokesman said Thursday afternoon that the vote "provides the clarity we've been waiting for to move forward" but did not offer a specific time table.

"We're on schedule to reach Mayor Faulconer's goal of choosing a pathway that achieves our renewable energy goals while also protecting ratepayers, and the mayor looks forward to making his recommendation in the next few weeks," said Craig Gustafson, a Faulconer spokesman, in an email.

A feasibility study released last year predicted a CCA in San Diego has the potential to deliver cheaper rates over time than SDG&E's current service, while providing as much as 50 percent renewable energy by 2023 and 80 percent by 2027.

"The city has already figured out we are still capable of launching a program, having competitive, affordable rates and finally offering families a choice as to who their energy provider is," said Capretz, who helped draft an initial blueprint of the climate plan as a city staffer.

SDG&E has come to the city with a counterproposal that offers 100 percent renewables by 2035.

Thus far, the utility has produced a rough outline for a "tariff" program that would charge ratepayers the cost of delivering more clean sources of energy over time.

Some council members have expressed frustration more specifics have not been sketched out.

SDG&E officials said they will take the new exit fee into account as they go forward with their counterproposal to the city council.

Speaking in general about the utility commission's decision, SDG&E spokeswoman Helen Gao called it "a victory for our customers, as it minimizes the cost shifts that they have been burdened with under the existing fee formula.

"As commissioners noted in rendering their decision, reforming the (exit fee) addresses a customer-to-customer equity issue and has nothing to do with increasing profits for investor-owned utilities," Gao said in an email.

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