Google’s model showing ‘before and after’ components of its packages including paper-stay tape, silicon adhesive, and a tray made from pulp rather than polystyrene plastic. Source: Heather Clancy/GreenBiz
Google will eliminate plastic from its consumer electronics packaging six months ahead of its self-imposed 2025 deadline. Google made its “plastic-free” pledge in October 2020.
The search giant will publish a 70-page guide in June so that other companies can see how it was done, said David Bourne, lead sustainability strategist for Google, during a session last week at Circularity 24, a GreenBiz event.
The company’s Pixel 8 smartphone, launched in October, was the first product under the new approach.
“You might think it’s sort of strange to enable other companies, potentially to enable other competitors,” Bourne said. “But our point of view on sustainability is that it really should be a collaborative endeavor. Innovation should be shared in sustainability, because if we sincerely want to create a sustainable future, then just a handful of companies being more sustainable isn’t going to achieve that.”
Google is encouraging those who use the guide to offer feedback.
Making sure design changes don’t frustrate consumers
The idea for the guide originated with the Google team working on the heaviest of its consumer products, TVs. They can weigh up to 40 pounds, said Katy Bolan, Google’s lead for environmental sustainability.
Google doesn’t make televisions, so it worked with manufacturing partners to deliver the goal, she said.
A major issue was ensuring that design changes weren’t frustrating for consumers, that they met Google’s aesthetic requirements and that they could be disposed of within existing recycling systems, said Miguel Arevalo, packaging innovation lead at Google. “It’s a bad experience if you have to think about it,” he said.
Google’s key design considerations
The new packaging is predominantly paper- and fiber-based, so it can be recycled easily. It required Google engineers, designers and suppliers to rethink lamination and coatings, box assembly, enclosures and labels, among other factors.
The company’s biggest challenges were:
Assessing how the elimination of plastic shrinkwrap would affect the durability and reliability of packages.
Determining whether size or shapes needed adjustments to accommodate “drop dynamics,” or what happens when an item is dropped.
Selecting new coatings and inks that met Google’s branding requirements: At least 50 solutions were reviewed. Suppliers that weren’t transparent about their impacts were eliminated quickly.
New ways to seal and waterproof the box, and to make sure it stays closed.
The reliability of closure labels and how easy they are to remove.
Weighing the future implications of substitutions, particularly for chemicals that could inadvertently result in higher greenhouse gas emissions.
One way to justify the extra cost
New paper-based packaging is likely to be more expensive than plastic, since they aren’t produced at the same scale. “When you first achieve something, it will be the most expensive version,” said Bourne.
That increase can be easier to support when considered as part of the total cost or if the expense is likely to decrease over time, the Google executives said. “We also see this as an investment,” Bourne said. “We are looking at sustainability as an augmentation of the consumer experience.”
Even zealots of the electric vehicle will tell you that public charging can be a fraught affair. If all goes well, and it often doesn’t, your charging session will likely entail sitting in a dark corner of a parking lot for upwards of an hour. You might have to stand in the rain or snow to operate the charger because most stations lack awnings. You might have to go hungry because many lack access to food. And, perhaps worst of all, your session may be made extra uncomfortable by a typical lack of restrooms.
But hopefully that’s changing. This year, Electrify America opened an indoor flagship location in San Francisco. Situated at 928 Harrison Street, this bank of 20 high-speed chargers is unique not only for its location—occupying some very expensive real estate—but also for its amenities. While charging, you can grab a drink from a vending machine, host a meeting from one of the lounges, and, yes, even use the bathroom.
Electrify America’s new flagship location in San Francisco. ELECTRIFY AMERICA
It’s a massive upgrade from what many EV early adopters have become accustomed to, but it’s just the beginning. With familiar roadside refuges such as Love’s Travel Stops and Buc-ee’s getting in on the game, the future is finally looking a bit brighter when it comes to electrification’s infrastructure.
Just as with buying a new house, the three most important factors in EV charging are location, location, and location. After all, the fastest, most reliable charger in the world is worthless if it isn’t where you need it. The good news? If you have off-street parking, you can likely put a charger in the best possible spot: your home. More than 90 percent of EV owners charge where they live. While slower than the high-speed units at public stations, at-home chargers more than make up for it in convenience.
The latter can typically bring an empty car to full in under ten hours, which is plenty of time for most folks to replenish their EV’s battery pack between returning from work and heading out again the next day. That potentially means a full charge every morning, so public installations take a back seat for many who use an EV as their daily commuter. That’s why we need far fewer of them than we do gas stations. However, whether road-tripping or just going for an extended Sunday cruise, most EV owners will still need to replenish their batteries in the wild at some point. And while location is still crucial, other factors are gaining significance.
The fastest, most reliable charger in the world is worthless if it isn’t where you need it. KENA BETANCUR/VIEW PRESS/GETTY IMAGES
Amaiya Khardenavis, an analyst of EV Charging Infrastructure at the energy-research firm Wood Mackenzie, says that there was a lot of “land grabbing” by the larger networks in the early days of EVs. That is, just throwing down chargers as close to major highways as possible with little regard for amenities. According to Khardenavis, today’s locations are more “customer-centric” than before. “The landscape in 2020 was dominated by only a few players in the market,” he says, “and these were all pure providers, like of course Tesla, but EVgo, Electrify America, ChargePoint, and that’s about it.”
Tesla gained an early advantage with its Supercharger network in 2012. Now, with more than 2,000 domestic locations, it’s the largest operator of fast chargers in the United States. But it wasn’t the first. ChargePoint is the nation’s largest network in general, launching back in 2007 and offering over 30,000 locations. Others weren’t far behind, including EVgo, which has about 3,000 chargers spread across 35 states.
“We’re addressing a lot of our legacy equipment . . . some of our chargers are getting close to a decade old,” says Katie Wallace, EVgo’s director of communications. Yet some newer players are helping to raise the bar. One of those is EV manufacturer Rivian, which launched its Adventure Network just 18 months ago and has since deployed 433 fast chargers across 71 locations. “We’re opening sites each week,” says Sara Eslinger, director of the program for Rivian.
The EVgo network comprises about 3,000 chargers across 35 states. JUSTIN SULLIVAN/GETTY IMAGES
While the name “Adventure Network” infers that these chargers are at off-road trailheads, and indeed Rivian offers some of those, Eslinger says the company is still focused on serving major transportation corridors, while ensuring availability of amenities like 24-hour food services and restrooms, even going so far as to bring in their own lighting if necessary. As increased EV adoption pulls new investment from some familiar names, features like these are becoming the next battleground.
According to Khardenavis, “More retail stores, retail chains, and travel centers [are] entering the space—Walmart, Pilot, and Flying J, as well as Love’s, everyone is trying to be involved in this space to some extent.” Though many of these partnerships are still developing (Mercedes-Benz just announced a deal with Buc-ee’s in November, for example), the net result should be a significantly improved charging experience.
The CEO of Rivian, Robert Scaringe, talks about the automaker’s Adventure Network plan at a presentation last month. PATRICK T. FALLON/AFP VIA GETTY IMAGES
Why are all these players getting into the market now? The money is starting to flow. In the beginning, running an EV-charging business was brutally complicated and expensive, and served only a small segment of early adopters. Today, utilization rates for public chargers are surging, and so is revenue.
“In our last earnings call, we reported that EVgo’s network throughout was growing five times faster than EVs in operation,” Wallace says. She adds that people are getting more comfortable driving their EVs, relying on chargers further afield.
Anthony Lambkin, vice president of operations at Electrify America, sees the same trend: “Some of our sites, especially in parts of California, are routinely over 50 percent utilization.” Lambkin refers to this as “massive growth,” and that it has driven the company to redesign some of its chargers, which were not up to surviving that intensity of use. Higher utilization means more money, and more money means more profits. But, as volume increases, so does the opportunity for other revenue streams.
Unlike these chargers in Oyster Bay, N.Y., an increasing number of future stations may have a retail-store component. ALEJANDRA VILLA LOARCA/NEWSDAY RM VIA GETTY IMAGES
“In today’s gas-station business model, over 60 percent of the revenue really comes from store purchases, not from fuel retail,” Khardenavis says. “The future of the EV-charging model will be some sort of co-located retail-store presence.” More chargers at nicer locations, though, means nothing if they’re constantly broken. “The bigger question is going to be how reliable are these chargers?” Khardenavis says. A 2022 study out of the University of California, Berkeley, found that roughly one out of four chargers evaluated in the Greater Bay Area was non-functional (Tesla stations were not included). More troublingly, when the researchers visited those sites a week later, nearly all of them were still not fixed.
Khardenavis says that such historically poor reliability is directly related to profitability: “I think with that kind of cash flow coming in . . . there is now an impetus to develop this model, which is more customer-centric than just earlier focusing on expanding to locations.”
More chargers at nicer locations means nothing if they’re constantly broken. JOHN TLUMACKI/THE BOSTON GLOBE VIA GETTY IMAGES
In the world of public charging, there’s Tesla’s Supercharger network, and then there’s everybody else. Tesla’s network not only earned a reputation for being the most readily available and reliable, but using a single plug across every new Tesla model meant owners only had to show up, plug in, and wait while the electrons flowed.
Various plug standards have come and gone for other manufacturers, but that too is changing. Virtually every major manufacturer has agreed to use what’s being called the North American Charging Standard. It’s essentially the same plug that Tesla uses.
Soon EVs from Ford, Rivian, and plenty of others will not only use the same plug, but will be able to easily charge at Tesla’s Supercharger stations across the nation. That’s the good news. The bad news is that all the non-Teslas on the road today use a combination of different plugs, most featuring the Combined Charging System, or CCS. While Tesla is updating some of its Supercharger installations to support CCS, it’s going to be a slow transition. “We’re going to be in a land of adapters for a while, because the soonest that any non-Tesla OEM is going to come out with the NACS port is probably the fall of 2025,” says Wallace.
Soon other EVs will not only have the same plug as Tesla models, but will be able to use Tesla’s Supercharger stations across the nation. CELAL GUNES/ANADOLU AGENCY VIA GETTY IMAGES
Rivian has updated its vehicles to show the location of all Superchargers on its integrated navigation, routing drivers appropriately depending on whether they have an adapter. Yet Khardenavis is concerned that this transition could slow down EV adoption further, with some buyers deciding to wait for the port transition to be completed before investing in a new EV. He fears that EVs with the “now-obsolete” CCS port could sit on dealership lots for longer.
Increased utilization raises the potential for long lines at chargers, but the process of building new stations entails dodging numerous roadblocks. One of those is working with local municipalities, which often aren’t used to moving at the pace of a startup. Electrify America’s Lambkin says that processes are improving, but it’s still a challenge. “Permitting is going much better for us now than it was five years ago because there are far more cities and towns and municipalities that are used to seeing this type of equipment,” Lambkin says. “Back in the day, it was like alien technology.”
The federal government is helping as well. The 2021 National Electric Vehicle Infrastructure (NEVI) program provides funding to help cover planning, construction, and even maintenance of chargers. “Folks are going to see a lot more stations coming online in the next year and a half,” says Wallace, who attributes this to the various Department of Transportation outposts at the state level becoming “more comfortable and more familiar with how to implement the NEVI program.”
U.S. President Joe Biden gets a demonstration of an EV charging setup at the White House. JIM WATSON/AFP VIA GETTY IMAGES
Another issue is grid capacity. Khardenavis notes that, for a larger installation, it can take upwards of a year just for the necessary upgrades to power the site. “Project delays are a very common theme in the fast-charging space especially,” he says. But the charging companies are finding ways around this, too. According to Lambkin, Electrify America routinely uses on-site batteries to offset energy usage during peak times and has a so-called “mega pack” in Baker, Calif. “That’s actually to allow us to build that site well in advance of when the utility, SCE in this case, had the capacity to be able to serve the number of dispensers and the amount of power that we needed.”
And finally, there’s construction. It takes time to design a given charger layout, run the conduit, lay out the chargers themselves, and wait for all that concrete to cure. Even that process is changing. “We just deployed our very first station using prefabrication in Texas,” says EVgo’s Wallace. “It’s just a more efficient way to deploy because everything is assembled off-site, in an assembly facility, and then dropped into a skid-frame. So this construction timeline is much shorter.”
Tesla owners line up for an available charger in Utah. GEORGE FREY/GETTY IMAGES
According to the National Renewable Energy Laboratory (NREL), current growth and demand for EVs will require 1.2 million U.S. public chargers by 2030. As to the current reality, Khardenavis notes that there are about 165,000 available today, and he’s skeptical about that 2030 target. “It’s almost ten-X growth, which is extremely challenging in today’s environment,” he says, adding that predicting the need for six years in the future is itself difficult given the unpredictability of consumer behavior. “I don’t see us reaching that number anytime in the next four- to five-year timeframe. But I think it’s a target that we need to have in mind before we deploy and make plans around making EV charging more ubiquitous.”
A couple wait on their EV to charge in Texas. SHELBY TAUBER FOR THE WASHINGTON POST VIA GETTY IMAGES
But merely adding more chargers isn’t enough. It’ll take a better all-around charging experience to meet the needs of a new generation of luxury EV owners, such as drivers of the Mercedes-Benz EQS and the Rolls-Royce Spectre, for example. Meeting those standards will take more installations like Electrify America’s indoor flagship. “We’re really competing with the traditional fueling industry, and that’s been around for 100 years,” says Lambkin. “If you think about where we are today and where we’ve come in just five years, think about the levels of improvement that we can expect to see over the next five years.”
While that dingy charger in the back of the shopping-mall parking lot is still the norm for now, there’s work underway to make it the outlier. The real issue remains whether public adoption of EVs and the requisite infrastructure expansion will both maintain enough juice.
Data centers, factories, heat pumps and EVs are putting increasing stress on a grid that isn’t growing fast enough, new data shows.
Written by: Jeff St. John View the original article here
A recently constructed Meta data center in Eagle Mountain, Utah (George Frey/Getty Images)
For the past two decades, demand for electricity across the United States has hardly increased. But those dynamics appear to have dramatically reversed — and U.S. electric utilities, regulators and power grid planners aren’t prepared to deal with this new paradigm of surging electricity demand.
That’s the key takeaway from a new report by consultancy Grid Strategies called The Era of Flat Power Demand Is Over. Already, massive amounts of clean energy projects are stuck waiting for grid expansions to happen so they can connect. Soon enough, data centers, factories, electric-vehicle charging depots and other major electricity users could start facing the same barriers, the report warns.
In the past year, estimates from U.S. utilities and grid operators of how much electricity demand will grow over the next five years have nearly doubled, jumping from 2.6 percent to 4.7 percent, according to Grid Strategies’ analysis. That’s far higher than the more incremental 0.5 percent annual demand growth estimates of the past decade.
(Grid Strategies)
Over the past 20 years, efficiency improvements — primarily replacing incandescent lightbulbs with fluorescents and then LEDs — have counterbalanced rising power demand from population and economic growth, giving utilities and regulators little reason to expand their power grids or generation capacity.
“I think people got used to…flat power demand,” said Rob Gramlich, Grid Strategies president.
But the combination of near-term growth in electricity use by data centers and industry and longer-term growth from electric vehicles and building heating has upended that status quo, he said. “Those who are actively involved in electrifying parts of the economy understand that that means more electricity demand. But it’s only been dribbling out anecdotally here and there.”
That anecdotal data has piled up. In Virginia’s Loudoun County, dubbed “Data Center Alley” for its remarkably high concentration of data centers, power shortfalls have prompted utility Dominion Energy to push grid planners to approve a multibillion-dollar grid expansion; some data center operators and regulators have even proposed running backup diesel generators to cover power gaps. In California, lags in grid expansions are causing monthslong wait times for getting connected to utility service, not just for major new loads like electric truck-charging depots but even for everyday commercial and multifamily buildings.
All told, grid planners across the U.S. forecast an increase of 38 gigawatts of peak demand by 2028, according to data reported to federal regulators — a pace of growth that will be hard to keep up with. Data centers and factories can be built in a few years, but it takes four years or more to build new power plants, and up to a decade or longer to build new transmission lines.
While this is a problem that goes beyond the clean energy sector, it also presents a particular hurdle for the energy transition. Not only does the U.S. need to rapidly replace existing coal- and gas-fired power plants with renewables — it also needs to grow fast enough to accommodate the surge of new electricity demand. For this new demand to be met in a way that doesn’t derail the transition away from fossil fuels, the U.S. will need to clear the way for a much speedier buildout of wind, solar, batteries and power lines.
“The main reason [tracking increases in electricity demand] is important is for infrastructure planning,” Gramlich said. “Transmission infrastructure in particular takes a long time. As soon as we know this load situation to be the case, we’d better act quickly.”
A sector-by-sector breakdown of where new electricity demand is coming from
Grid Strategies highlighted key demand-growth drivers across several major grid regions, including PJM, which operates the grid in all or part of 13 states from Illinois to Virginia, as well as the grid operators for California, New York and Texas, and four large utilities: Arizona Public Service, Duke Energy, Georgia Power and Portland General Electric in Oregon.
(Grid Strategies)
Data centers and industrial facilities were among the biggest drivers of new load. New investments in U.S. data centers are projected to exceed $150 billion through 2028, driven by rising demand for cloud computing, telecommunications, digitization and artificial intelligence. Data centers already make up roughly 2.5 percent of total U.S. electricity demand, according to analysis from Boston Consulting Group — but exploding demand for AI could drive that to 7.5 percent by 2030.
(Grid Strategies)
New industrial facilities are also adding demands on the grid. The country has seen about $481 billion in commitments to build and expand industrial and manufacturing facilities since 2021, the report states. Much of that growth stems from the clean energy manufacturing boom and is concentrated in the Midwest and Southeast, which are receiving the lion’s share of battery and EV manufacturing investments spurred by the tens of billions of dollars of federal incentives from the Inflation Reduction Act.
(U.S. Department of Energy)
Not all of the emerging demands for grid electricity are fully accounted for in current load-growth forecasts, Gramlich noted. One striking example is hydrogen produced from zero-carbon electricity, supported by lucrative tax credits offered by the Inflation Reduction Act, which could add gigawatts’ worth of new power demand across the country. But with the exception of New York, grid planners’ “load forecasts don’t appear to be explicitly considering the implications of hydrogen fuel plants,” according to the repo
(U.S. Department of Energy)
Increased electricity demand stemming from the electrification of transportation and buildings — a key facet of the Biden administration’s climate plans — is not as granularly tracked in states outside those with aggressive policies on those fronts, such as those adopted by California and New York. In California, where policymakers have set their sights on replacing fossil-fueled vehicles and building heating systems with EVs and heat pumps, respectively, statewide electricity demand is expected to grow by about 60 percent through 2045, according to an analysis from utility Southern California Edison — a remarkable turnaround from a state that’s led the country on energy efficiency. New York expects similar increases in electricity demand over the coming decades.
How uncertainty and cost concerns have limited grid infrastructure buildout
Though it’s clear what direction power demand is moving in, “we don’t know enough yet to say what load growth is going to be,” Gramlich cautioned. Load forecasting is an inherently uncertain field. Some proposed data centers and factories may never be built. The uptake rates of EVs or electric-powered heat pumps for homes and buildings can’t be predicted with perfect accuracy.
These uncertainties can lead utility regulators to look askance at utility grid-expansion proposals that may exceed future needs, since their costs are passed on to utility customers via increases on their bills. Over the past half-decade or so, a number of large-scale utility grid-expansion plans have been denied by state regulators due to concerns over excessive costs.
Similar dynamics have slowed efforts within the independent system operators and regional transmission organizations that manage the grids that provide electricity to roughly two-thirds of the country’s population. Since a series of large-scale buildouts in the early 2010s, the scale of U.S. grid projects has declined significantly, with the average miles of newly built high-voltage transmission lines falling by more than half from the first half to the second half of that decade.
Several of these grid operators have approved multibillion-dollar grid buildout plans in the past two years. But those plans still tend to project lower levels of load growth than the data in Grid Strategies’ study indicates is on its way, Gramlich said. “It may be that everybody’s base case needs to be ratcheted up.”
The Federal Energy Regulatory Commission, which regulates interstate transmission policy, is in the midst of crafting proposed transmission rules that are expected to require grid operators and utilities to examine a broader set of future grid needs, including increasing demand from electrification of transport and buildings, when making their long-term grid plans.
“There should be a lot of work coming up for every region following the FERC rule,” which is expected some time in the first half of 2024, Gramlich said. “That rule will require a lot of planning — and the devil’s in the details in every region.
New industrial facilities are also adding demands on the grid. The country has seen about $481 billion in commitments to build and expand industrial and manufacturing facilities since 2021, the report states. Much of that growth stems from the clean energy manufacturing boom and is concentrated in the Midwest and Southeast, which are receiving the lion’s share of battery and EV manufacturing investments spurred by the tens of billions of dollars of federal incentives from the Inflation Reduction Act.
(U.S. Department of Energy)
Not all of the emerging demands for grid electricity are fully accounted for in current load-growth forecasts, Gramlich noted. One striking example is hydrogen produced from zero-carbon electricity, supported by lucrative tax credits offered by the Inflation Reduction Act, which could add gigawatts’ worth of new power demand across the country. But with the exception of New York, grid planners’ “load forecasts don’t appear to be explicitly considering the implications of hydrogen fuel plants,” according to the report.
(U.S. Department of Energy)
Increased electricity demand stemming from the electrification of transportation and buildings — a key facet of the Biden administration’s climate plans — is not as granularly tracked in states outside those with aggressive policies on those fronts, such as those adopted by California and New York. In California, where policymakers have set their sights on replacing fossil-fueled vehicles and building heating systems with EVs and heat pumps, respectively, statewide electricity demand is expected to grow by about 60 percent through 2045, according to an analysis from utility Southern California Edison — a remarkable turnaround from a state that’s led the country on energy efficiency. New York expects similar increases in electricity demand over the coming decades.
How uncertainty and cost concerns have limited grid infrastructure buildout
Though it’s clear what direction power demand is moving in, “we don’t know enough yet to say what load growth is going to be,” Gramlich cautioned. Load forecasting is an inherently uncertain field. Some proposed data centers and factories may never be built. The uptake rates of EVs or electric-powered heat pumps for homes and buildings can’t be predicted with perfect accuracy.
These uncertainties can lead utility regulators to look askance at utility grid-expansion proposals that may exceed future needs, since their costs are passed on to utility customers via increases on their bills. Over the past half-decade or so, a number of large-scale utility grid-expansion plans have been denied by state regulators due to concerns over excessive costs.
Similar dynamics have slowed efforts within the independent system operators and regional transmission organizations that manage the grids that provide electricity to roughly two-thirds of the country’s population. Since a series of large-scale buildouts in the early 2010s, the scale of U.S. grid projects has declined significantly, with the average miles of newly built high-voltage transmission lines falling by more than half from the first half to the second half of that decade.
Several of these grid operators have approved multibillion-dollar grid buildout plans in the past two years. But those plans still tend to project lower levels of load growth than the data in Grid Strategies’ study indicates is on its way, Gramlich said. “It may be that everybody’s base case needs to be ratcheted up.”
The Federal Energy Regulatory Commission, which regulates interstate transmission policy, is in the midst of crafting proposed transmission rules that are expected to require grid operators and utilities to examine a broader set of future grid needs, including increasing demand from electrification of transport and buildings, when making their long-term grid plans.
“There should be a lot of work coming up for every region following the FERC rule,” which is expected some time in the first half of 2024, Gramlich said. “That rule will require a lot of planning — and the devil’s in the details in every region.”
Building new power plants instead of transmission lines could help serve these growing loads. But it’s far more efficient to expand the grid to carry power from where it’s most cheaply generated to where it’s most acutely needed.
A host of new transmission grid projects have been approved over the past few years. But they’re still not enough to connect the massive amounts of new renewable power needed to reach the Biden administration’s goals of a zero-carbon grid by 2035. Studies from the U.S. Department of Energy, the Massachusetts Institute of Technology and Princeton University have found the country must double or triple current transmission capacity to reach that goal.
Nor are the new power lines being planned sufficient to eliminate rising grid-congestion costs that are adding billions of dollars to U.S. consumers’ electricity costs, or to enable different regions of the country to share power in order to mitigate the risk of blackouts during extreme winter storms or summer heat waves. This new report also adds the risk of stalling economic growth to this list of threats.
Transmission projects can take more than a decade to move from planning to construction, and they can be blocked by permitting and legal challenges at multiple points. Regional grid-expansion proposals can be scuttled due to conflicts between the utilities and states they connect over how to fairly allocate and distribute the costs of building them.
Federal action on this front has been limited as well. To date, Congress has failed to act on proposed legislation to offer tax incentives to transmission projects, to require minimum amounts of transmission between regions or to give FERC more authority to override state-by-state objections to new projects. But members of both parties in Congress “should care enough about infrastructure to support economic growth in this country,” Gramlich said.
Contributed by Grzegorz Marecki, co-founder and CEO of Continuum Industries View the original article here
The expansion of electricity transmission infrastructure is crucial for meeting growing energy demands and accelerating the United States’ clean energy transition. However, spatial planning processes are struggling to keep pace with the speed of change required to tackle climate change. Building clean energy infrastructure today can take more than a decade, largely due to delays in planning and permitting.
The root of this challenge lies in the complexity of infrastructure planning. Developers need to simultaneously meet the requirements of dozens of stakeholders, which demands a balance between technical and regulatory considerations, as well as the perspectives, priorities, and concerns of diverse stakeholders. Utilities, traditionally functioning as asset managers, are now faced with the need to become developers, driving the rapid expansion of America’s grid demands. However, their processes have not evolved at the pace required to meet this urgent need.
Additionally, as the volume of work increases, the industry grapples with insufficient resources to deliver at the speed required. Automation of repetitive tasks can help free up professionals, enabling them to focus on more complex challenges. The industry also faces constraints due to the limited number of specialists available for traditional tasks.
To overcome these challenges, the industry must embrace a technology-powered paradigm shift. A tech-enabled approach to planning processes, supported by professional oversight, has the potential to revolutionize the development of new energy networks.
Frontloading data for more predictable permitting
With the advancement of technology, governments and other key stakeholders now have access to unprecedented amounts of data. If harnessed effectively, this data can help infrastructure developers expedite decision-making processes and streamline the planning and permitting phases.
New tools allow for a comprehensive data dive right at the project’s start, providing a full picture of constraints and opportunities. AI algorithms offer intelligent insights, guiding developers toward optimal decisions. These tools empower users by allowing them to configure assumptions, preferences, and project goals before the algorithm runs, ensuring a clear link between inputs and outputs. For example, easier access to spatial data makes it possible for developers to get a comprehensive view of the permits that would be required. Traditionally, they would have to wait a few months for a manually produced report from a consultant. This also allows the professionals to focus on the areas of highest risk.
Automated routing for unbiased solutions
By automating routine processes, developers can assess more alternatives than was ever possible without automation and remove decision biases. Algorithms can explore and optimize different solutions for infrastructure assets, simultaneously considering factors such as cost, technical feasibility, and environmental and community impact.
While still in its early stages of adoption in the US, automated routing is already demonstrating its potential, and it might pay to look across the pond for an example to follow. The UK is slightly ahead of the US when it comes to grid expansion, and more than just encouraging is now expecting transmission companies to standardize and automate routing. The government has adopted a package of 19 measures to slash the project development timeline from 14 to 7 years, but utilities that have adopted a heavily automated approach say that they’ve been able to kick-start their projects and complete 12 months’ worth of work in as little as 8 weeks.
As the energy sector transforms and projects become increasingly complex, automated tools will empower developers to respond swiftly to changing requirements, market dynamics, and regulatory landscapes.
Transparency and accountability through comprehensive decision-making
In the past, manual record-keeping and documentation processes left room for ambiguity and potential oversights. However, technology can establish a reliable audit trail, ensuring that every decision is logged, timestamped, and linked to the specific dataset or analysis that influenced it. This record enables project teams to revisit and refine decisions, supporting external regulatory approvals and fostering accountability throughout the process.
Breaking silos with cross-department collaboration
Technology can also bridge the divide between internal teams, fostering smooth collaboration and streamlining decision-making processes. Providing a shared platform for data and insights ensures that everyone involved in the project is working from the same information, reducing miscommunication and delays.
Through leveraging technology, traditionally siloed disciplines can replace slow email communication channels with rapid feedback based on standard criteria. For example, when engineers move a tower to avoid difficult ground conditions closer to a water body, they receive automatic feedback on whether the new position meets the requirements for setbacks from the water based on environmental protection policies.
Public engagement and transparent project narratives
Beyond internal teams, technology plays a crucial role in engaging the public and garnering support for critical infrastructure projects. Presenting decisions backed by solid evidence and interactive visualizations makes complex data digestible and addresses concerns head-on. This transparency builds trust and fosters a sense of shared ownership, crucial for navigating the permitting process and ensuring community buy-in.
Stakeholder engagement is also changing thanks to technology. Dynamic maps and immersive 3D visualizations now allow project teams to collaboratively iterate with stakeholders, demonstrating the project’s evolution over time and minimizing impacts. This interactive approach, coupled with routing and siting automation, eliminates the traditional time constraints associated with manual rerouting.
The submission of documents, particularly environmental baseline schedules and reports, has also evolved. Algorithms can now identify potential impacts, presenting them to professionals for screening and defining mitigation strategies. This not only speeds up the process but also frees up professionals for more strategic tasks.
The Linear Infrastructure Planning Panel provides a noteworthy example of the efforts made towards more transparent and dynamic project planning. The Panel’s purpose is to engage key public interest stakeholders, including social and environmental groups, in the development of good practices and ethical approaches in the use of new techniques, such as algorithms and advanced software tools, for infrastructure planning. By actively involving various stakeholders, the Panel contributes to shaping responsible and inclusive technology integration in the planning process, setting a precedent for the industry.
Looking ahead
The American Council on Renewable Energy emphasizes that a $1.5 trillion investment in new transmission infrastructure by 2030 is not just a financial commitment, but an investment in a clean energy future. In this landscape, technology is not a silver bullet, but still a powerful catalyst for change. It facilitates efficiency, transparency, and collaboration, enabling informed decision-making and accelerating the development of a robust and resilient grid.
By embracing a tech-powered approach, the US can overcome the bottlenecks plaguing the current system and realize the full potential of clean energy. This transformation isn’t about replacing human expertise; it’s about empowering and augmenting it, fostering a synergy that paves the way for a more efficient and sustainable future.
With COP28 recent in the rearview mirror, 2024 represents a clear and critical inflection point for confronting the climate crisis. New rules in the European Union and in California, the world’s fifth-largest economy, will change how global businesses report risks, purchase energy and manage supply chains. The effects of the Inflation Reduction Act in the U.S. are still emerging: 175 nations are hashing out the first global treaty to end plastic waste.
Below are some defining moments that will drive change in the business of sustainability in the coming year.
Carbon
Expected U.S. SEC climate-related disclosures in April will require companies to report their GHG emissions.
The U.S. Office of Fossil Energy and Carbon Management, part of the Department of Energy, announces winners in February of its carbon dioxide removal purchase pilot prize and will publish details for corporate sustainability teams’ own carbon removal due-diligence processes.
New guidance from the Science Based Targets initiative on the use of environmental attribute certificates, including carbon credits, in decarbonization goals should come out by summer.
By the end of 2024, companies subject to California’s new Climate Corporate Data Accountability Act (SB253) will need to establish processes for auditing their 2025 emissions ahead of 2026 reporting.
Finance and ESG
A new proposal may emerge in the spring from the U.S. Securities and Exchange Commission (SEC), after it again delayed its climate change disclosure rulemaking.
Changes to the EU’s Sustainable Finance Disclosure Regulation (SFDR) 2.0 are likely following a September 2023 review.
Sometime in 2024, the U.S. Federal Trade Commission’s updated Green Guides are expected to update what “greenwashing” means in business and marketing.
Nature and biodiversity
The EU’s Corporate Sustainability Reporting Directive (CSRD), requiring companies to disclose their risks from environmental and social factors, takes effect Jan. 1.
COP16, the 16th Conference of the Parties to the Convention on Biological Diversity, will take place in Colombia from Oct. 21 to Nov. 1.
Revised or updated National Biodiversity Strategies and Action Plans (NBSAPs), including national targets, are due by COP16.
By Dec. 30, operators and traders must prove deforestation-free sourcing for targeted commodities in the EU market. That’s the EU Deforestation Regulation (EUDR) compliance deadline.
Food and agriculture
The EU CSRD goes into effect as 2024 begins, influencing supply chain impact disclosure and bringing new evidence of deforestation.
Supply chains risk disruptions if the U.S. Farm Bill continues to stall in Washington in 2024.
Watch for the next steps from the hundreds of nations that signed sustainable food declarations at COP28.
Transport
The U.S. Departments’ of Treasury and Energy rules go into effect, barring vehicles with battery components from a “foreign entity of concern” from consumer tax credits.
The IRS expands its EV tax benefit by letting consumers choose between claiming a credit on their tax returns or using the credit to lower a car’s purchase price.
The ReFuelEU aviation initiative goes into effect Jan. 1 to advance sustainable aviation fuels (SAF) in the European Union. It also requires aircraft operators and EU airports to work towards emission reductions and to ensure a level playing field for airlines and airports.
In January, the EU extends its cap-and-trade Emissions Trading System (EU ETS) to regulate CO2 from large ships of any flag entering its ports.
The U.S. Department of Energy will release an updated Greenhouse Gases, Regulated Emissions, and Energy Use in Transportation (GREET) model by March 1.
Circular economy
A hoped-for Global Plastics Treaty in 2024 moves forward with INC-4 meetings expected in April in Ottawa and INC-5 by November in Korea.
California, Maine, Oregon and Colorado are working on enforcement rules and other fine print for their new extended producer responsibility (EPR) packaging laws.
EU battery regulations are gradually being introduced, encouraging a circular economy for batteries.
Energy
At COP28, the U.S. announced new rules to cut methane emissions in oil and gas production, likely to change the energy cost equation. Watch for progress from 150 countries pledging two years ago to cut methane by 30 percent by 2030.
The Biden administration will be giving out $7 billion for its Regional Clean Hydrogen Hubs (H2Hubs).
2024 will be a watershed year for microgrids moment: Interconnection backlogs are creating a new value-add for microgrids, especially as the macrogrid can’t keep up with electricity demand.
Buildings
Watch the 28 countries agreeing at COP28 for “near-zero” buildings by 2030 through the Buildings Breakthrough.
Applications are due and funding will be announced for the EPA’s $27 billion Greenhouse Gas Reduction Fund, backing climate tech and moving money into communities.
Applications for the EPA’s Environmental Product Declaration (EPD) grants are due Jan. 16 from manufacturers.
Over the last decade, companies and investors have come to pay more attention to environmental concerns, often with a goal of offering “green” products or making “green” investments. But the companion of green is often what’s known as greenwashing. In some countries, regulators are trying to clean up the field, launching investigations and levying fines. They have the backing of some advocates of environmentally minded investing worried that greenwashing’s taint may undermine the field.
1. What is greenwashing?
It’s the use of misleading labels or advertising to create an undeserved image of environmental responsibility. Here are some eamples:
In December, the UK’s antitrust regulator began an investigation of Unilever Plc, the maker of Dove soap and Cif cleaner, for allegedly overstating the environmental qualities of certain products.
Fashion companies Asos and Boohoo and airlines such as Air France-KLM, and Deutsche Lufthansa AG were told by regulators to discontinue misleading ads that made air travel seem more eco-friendly than it is.
In investing, the UK’s Financial Conduct Authority rolled out a framework in November designed to protect retail investors from misleading claims by firms with so-called ESG funds — where investment decisions are shaped by environmental, social or governance factors.
In the US, Deutsche Bank AG’s DWS asset management arm agreed in September to pay a total of $25 million to settle Securities and Exchange Commission probes into alleged greenwashing and anti-money laundering lapses. The penalties included $19 million for “materially misleading statements” about how the bank incorporated ESG factors into research and investment recommendations.
2. What’s the incentive for greenwashing?
The ultimate attraction is the favorable image companies project across to clients, investors, shareholders, lenders and even potential employees. But different players have different reasons for exaggeration. When companies fudge on something they’re selling, it’s because they want environmentally minded consumers to be drawn to their products. When they’re borrowing money, they may be chasing a “greenium” — the money they can save by qualifying for the better terms lenders might extend to green or social projects or to ones with ESG goals. Brazil raised $2 billion in the bond market in November 2023 with proceeds earmarked for green and social work, and the debt was priced lower than initial guidance – meaning the Amazon forest nation is paying lower interest rates, compared with a conventional bond. And investment managers might put a greener label than is warranted on a fund to draw in more assets.
3. How big a problem is it?
In 2022, Bloomberg News analyzed more than 100 bonds worth almost $70 billion tied to issuers’ ESG credentials that were sold by global companies to investors in Europe. The analysis found that the majority were tied to climate targets that were weak, irrelevant or even already achieved. Some companies promised to do no more than maintain their existing ESG ratings. And some of the fastest-growing areas of ESG financing involve so-called sustainability-linked loans(SLL) (and similar bonds) in which the connection between environmental labels and environmental goals can be tenuous.
4. How does sustainability-linked debt work?
Sustainability-linked bonds and sustainability-linked loans are signed with commitments from borrowers to achieve certain environmental or social targets, but those goals may be changed in an increasing number of cases. The more flexible agreements even allow issuers to adjust those targets under certain conditions without incurring a penalty. Issuers argue that they have to look for ways to cope with increasingly volatile markets in which key ESG parameters such as energy prices become harder to predict. Then there’s the “sleeping” sustainability-linked debt where financing has an ESG label but with no immediate sustainability targets. Other approaches push responsibility even further out: Bank of China Ltd.’s so-called re-linked bond sold in 2021 is tied to the performance of a pool of sustainability-linked loans made to its clients — that is, not to anything BOC is or isn’t doing in ESG terms, but to the ESG performance of the clients who have taken out those loans.
5. Who’s checking up?
There are dozens of ESG rating and data providers globally, which can provide some assurance that companies and debt issuers are doing their part in sustainability. But private ratings systems can be unreliable and corporate reporting is spotty and hard to compare. All of this greenwashing detective work would be easier if investors and the public had a standardized approach and a robust set of data to compare. Here’s some of what governments and other organizations are doing:
Hong Kong, Japan, South Korea, India, Singapore, the UK and EU have issued or proposed rules for ESG score providers, though the rules are only mandatory in the EU and India. The UK Financial Conduct Authority, meanwhile, has unveiled its Sustainability Disclosure Requirement ensuring investment products are accurately labeled or presented.
The US SEC is working on getting companies to report on their greenhouse gas emissions and other climate matters.
The EU enforced the Corporate Sustainability Reporting Directive in January 2023 which requires companies to disclose risks and opportunities arising from social and environmental issues. For the debt markets, the European Council adopted a green bond standard in October 2023 that specifies where proceeds will be invested and which activities are aligned with the EU taxonomy.
Financial bodies, including the International Capital Market Association which oversees the international debt capital markets, and global loan associations have drafted guidelines for ESG debt such as sustainability-linked instruments, green and social financing.
6. Is it just environmental misconduct that’s considered greenwashing?
No. Social and governance aspects have grown to be just as crucial as companies’ environmental efforts, especially since the #MeToo and Black Lives Matter movements began making an impact on consumers’ spending. Many corporations are using their annual sustainability reports to showcase how fair they are in equality employment or what they did to improve employee wellbeing. Given that some of these goals are hard to measure in areas where little data is available, there’s a risk in overstating the results. Of the $1.4 trillion of sustainability-linked debt with disclosed ESG goals, only $352 billion was tied to social objectives, according to BloombergNEF data.
7. How can I avoid investing in greenwashing?
Here are some questions to ask yourself:
How ambitious are a company’s goals? Are they integral to its core business, or just superficial commitments? Is the company just promising to do something it would be doing anyway?
How specific is the timeframe? Are the goals set annually, or in a way that allows for easy monitoring?
Are companies looking at the full “scope” of their emissions, including the carbon released when customers use their products?
How much do their plans rely on the kinds of carbon “offsets” that have come under fire for not living up to their promises of environmental benefits?
Is there a way to check on companies’ claims, such as in an evaluation by an impartial ESG data- or ratings-provider?
Is a company making information about their sustainability goals accessible in a transparent and timely way?
Published By: Start US Insights View the original article here
Energy storage is undergoing a rapid transformation wherein research is underway to develop efficient long-lasting solutions. It is a critical component of the manufacturing, service, renewable energy, and portable electronics industries. Currently, the energy storage sector is focusing on improving energy consumption capacities to ensure stable and economic power system operations. Broadly, trends in energy storage solutions can be categorized into three concepts:
Moving away from the traditional lithium-ion batteries toward innovative battery chemistries that offer greater stability, density, and shelf life.
Developing storage solutions that store intermittent renewable energy efficiently and also scale it up to power large geographical areas.
Transitioning from centralized energy storage to a more flexible and portable distributed form of energy storage.
This article was published in August 2022 and updated in September 2023.
Innovation Map outlines the Top 10 Energy Storage Trends & 20 Promising Startups
For this in-depth research on the top global decarbonization trends and startups, we analyzed a sample of 1366 global startups & scaleups. This data-driven research provides innovation intelligence that helps you improve strategic decision-making by giving you an overview of emerging technologies and trends in the energy industry. In the Energy Storage Innovation Map, you get a comprehensive overview of the innovation trends & startups that impact your company.
These insights are derived by working with our Big Data & Artificial Intelligence-powered StartUs Insights Discovery Platform, covering 3 790 000+ startups & scaleups globally. As the world’s largest resource for data on emerging companies, the SaaS platform enables you to identify relevant technologies and industry trends quickly & exhaustively.
Tree Map reveals the Impact of the Top 10 Energy Storage Trends
Based on the Energy Storage Innovation Map, the Tree Map below illustrates the impact of the Top 10 Energy Industry Trends. Companies and research organizations are developing advanced lithium battery chemistries and lithium alternatives. These innovations combat the peak energy demand from the grid. The immediate need to control this energy demand is advancing utility-scale and distributed energy storage solutions.
The electric vehicle (EV) and electronics industry depending on electric grids and on other distributed energy sources require quick charging and, hence, there is a growing demand for short-duration energy storage (SDES) devices. Due to the low recyclability and rechargeability of lithium batteries, alternate forms of batteries such as redox and solid-state are also rising. Additionally, innovative thermal and hydrogen storage technologies reduce the carbon footprint of the energy storage industry. Lastly, industrial energy consumers are leveraging energy storage as a service to incorporate renewable energy and address energy demands.
Global Startup Heat Map covers 1366 Energy Storage Startups & Scaleups
The Global Startup Heat Map below highlights the global distribution of the 1366 exemplary startups & scaleups that we analyzed for this research. Created through the StartUs Insights Discovery Platform, the Heat Map reveals that UK and US see the most startup activity, followed by other Western European countries.
Below, you get to meet 20 out of these 1366 promising startups & scaleups as well as the solutions they develop. These energy storage startups are hand-picked based on criteria such as founding year, location, funding raised, and more. Depending on your specific needs, your top picks might look entirely different.
Top 10 Energy Storage Trends in 2024
1. Advanced Lithium-Ion Batteries
Lithium-ion batteries offer advantages such as portability, fast recharging, low maintenance, and versatility. However, they are extremely flammable, sensitive to high temperatures, require overcharge or complete discharge protection, and suffer from aging. Moreover, there is a huge environmental implication to mining the components for battery manufacturing.
Therefore, startups are modifying lithium-ion batteries to increase their performance and lifetime. To achieve this, lighter and energy-dense materials like li-polymer, li-air, li-titanate, and li-sulfur replace the traditional lithium-cobalt electrodes. In addition, some startups recycle used batteries, advancing the circular economy.
Green Li-ion advances Lithium-ion Battery Recycling
Green Li-ion is a Singaporean startup that recycles lithium-ion batteries to produce battery cathode. The startup’s modular processing plants use co-precipitation hydrometallurgical technology in contrast to the conventional processes that use leaching reagents. This results in purity enhancement while reducing the production time of the rejuvenated cathode. Battery manufacturers utilize this solution for recycling batteries without the need for sorting.
Echion Technologies produces Lithium-ion Anode Material
UK-based startup Echion Technologies produces lithium-ion battery anode material for super fast charging. The startup’s anode material uses a proprietary mixed niobium oxide (XNO) technology which includes designing microcrystals with diffused lithium-ion. This enables fast charging without the need to use nanosized powders. Due to their high energy density, the applications of these anodes range from consumer electronics to the EV industry.
2. Lithium Alternatives
Lithium batteries are not environmentally friendly and it is hard to keep up with the increasing demand for lithium. These limitations are encouraging companies to look for alternative battery materials that power the next generation of battery storage. For instance, zinc-air batteries are a viable alternative to lithium given zinc’s abundant supply, inherent stability, and low toxicity.
Another efficient alternative is sodium-sulfur batteries. These batteries feature longer lifespans, greater charge/discharge cycles, high energy density, and are fabricated of relatively inexpensive materials. Some other promising battery chemistries are aluminum ion batteries, magnesium ion batteries, nickel-zinc batteries, and silicon-based batteries.
Offgrid Energy Labs develops Zinc-based Battery Technology
Indian startup Offgrid Energy Labs develops ZincGel, a proprietary battery technology. It uses a highly conductive zinc electrolyte and carbon-based cathode. The zinc electrolyte is self-healing, temperature-stable, and does not evaporate, thereby warranting a higher life. Moreover, the lack of side reactions and gas evolution ensures high coulombic and roundtrip efficiency. Two-wheeler EV manufacturers leverage this technology as a safe, eco-friendly, non-flammable, and sustainable alternative to the lithium-ion battery.
Altris creates Sodium Battery Cathodes
Altris is a Swedish startup that creates Fennac, a cathode material for use in sodium-ion batteries. The startup produces it using patented low temperature and pressure synthesis technology. It offers a low-cost, sustainable alternative to other electrode materials like alloys and hard carbon, without sacrificing performance. Battery-producing companies use this solution to implement it into their existing production lines and also find use in applications such as photochromic windows.
3. Short Term Response Energy Storage Devices
Devices such as supercapacitors, flywheels, and superconducting magnetic storage have existed for a very long time. Current battery technologies harness their potential in offering high power density for shorter time fractions. Even though they discharge quickly, they improve the quality and reliability of the power grid during transient periods such as after system disturbance, load changes, and line switching.
They also prevent the collapse of power grids due to voltage instability. Further, several startups integrate SDES into fuel cell applications to improve the charge-discharge cycle of electric vehicles. Many cities are also coupling their energy storage systems to SDES and noticed improvements in overall energy storage and charge cycles.
EEXION makes Supercapacitors
Israeli startup EEXION enables energy storage using supercapacitors. The startup’s proprietary product, Energize-N’-Go, is a chemically manipulated cell that uses pure carbon materials to achieve faster charging in comparison to rechargeable batteries. The recyclability and a near-infinite number of charge-discharge cycles make it apt for electric mobility applications.
GODI manufactures Hybrid Capacitors
GODI is an Indian startup that manufactures biowaste-derived hybrid capacitor material. The startup’s capacitor combines activated carbon and graphene which delivers short-term peak power required for fast charging. The extension of the solution from cell to module-level finds applications in automotive, renewable energy, and regenerative braking.
4. Battery Energy Storage Systems
Even though renewable energy technologies are more efficient and economical than ever before, they are highly intermittent in nature. Therefore, they need complementary solutions to fill in the availability gaps. Long-duration energy storage solutions ensure that renewable energy dominates power plant expansion but also overtakes traditional sources of energy.
As more and more clean energy sources are tied to the grid, the electricity infrastructure becomes better suited to tackle the changing demands. The risk of disruption also reduces significantly. Moreover, large-scale renewable energy storage improves the overall resilience of energy systems and accelerates the clean energy transition.
Albion Technologies offers a Smart Battery Energy Storage System
UK-based startup Albion Technologies makes battery energy storage systems (BESS) that serve renewable energy providers, developers, and grid operators. The startup’s product, Smart BESS, is a containerized system that enhances the battery lifetime and delivers over 90% usable energy. The solution is flexible and can be deployed almost anywhere and integrated with other units to meet diverse power and energy requirements.
Smart BESS is equipped with all the essential components, such as batteries, inverter, HVAC, fire protection, and auxiliary systems. It complies with the G99 UK national grid standards and enables the storage of clean energy from renewable sources, thereby reducing CO2 emissions and oil consumption.
Genista Energy designs Lithium-Iron Phosphate Battery Storage
Genista Energy is a UK-based startup that designs a lithium-iron phosphate-based battery energy storage system. It consists of a large container with several battery strings. The startup interconnects several such containers to obtain a scalable system to provide power in remote locations. Genista Energy offers power to industrial and commercial buildings while providing renewable energy management and an alternative to diesel generators.
5. Advanced Thermal Energy Storage
Heat storage, both seasonal and short-term, is an important means for affordably balancing high shares of variable renewable electricity production. The process of thermal energy storage includes providing heat to the storage system for removal and use at a later time. Conventionally, heating companies store hot or cold water in insulated tanks to use when demand increases to manage peaks in district heating and district cooling.
However, the developments in the few years showcase the use of new mediums such as molten salts, eutectic, and phase-changing materials to store heat energy. The most common application for thermal energy storage is in solar thermal systems. This overcomes the challenge of intermittent renewable energy and enables access to stored solar power at night.
HeatVentors offers Phase Changing Material (PCM)-based Thermal Storage
Hungarian startup HeatVentors makes phase-changing material-based thermal energy storage systems. The startup’s product, HeatTank, uses melting and solidification of phase change materials to store thermal energy. The use of these PCMs also saves space, energy, and cost by balancing the efficiency of the cooling and heating system. Companies providing heating, ventilation, and air conditioning (HVAC) systems utilize this solution to improve stability and peak performance management.
Cowa Thermal Solutions is a Swiss startup that produces capsule-filled heat tanks for thermal energy storage. The startup’s solution, BOOSTER CAPSULES, utilizes naturally occurring salts as raw materials. The capsule-filled tanks have three times the storage capacity compared to normal water storage tanks without capacity or stability loss. As a result, the heating tank becomes energy-dense and less dependent on the main power. The distributed energy industry leverages this solution in combination with a photovoltaic (PV) system to provide continuous heating.
6. Enhanced Redox Flow Batteries
Redox flow batteries are used as fuel cells or rechargeable batteries. They consist of two interconnected tanks both containing electrolyte liquids and oppositely charged electrodes, where ions pass from one tank to another via a membrane. Redox flow batteries offer longer lifespans than lithium batteries as the flow of current from one tank to another does not degrade the membrane.
Moreover, due to their flexible system design and easy scalability, they offer great potential for utility-scale integration of renewable energy. Advances in the field focus on developing new redox chemistries that are cost-effective and offer greater energy density.
US-based startup XL Batteries offers saltwater-based non-corrosive flow batteries. The startup uses organic molecules from inexpensive, industrial feedstock to store charge in the battery. Since dissolved charge storage molecules flow over electrodes in a separate stack during charging and discharging, independent sizing is possible. The mild salt water-based chemistry also renders the battery inexpensive in comparison to vanadium flow batteries. The utility industry leverages this technology as an alternative to expensive lithium-ion batteries.
StorEn Technologies is a US-based startup that develops vanadium flow battery technology. The property of vanadium allows the production of batteries with only one electroactive element as opposed to two, eliminating metal cross-contamination. They overcome the issue of decay and capacity loss in lithium batteries. StorEn Technologies’ batteries are apt for telecom tower batteries that source power from the electrical grid and renewable energy in off-grid locations.
7. Distributed Storage Systems
Energy generation and storage systems traditionally follow a centralized architecture. This increases grid failure risks during high energy demand periods, which may disrupt the energy supply chain. Distributed storage systems, on the other hand, address this challenge by allowing individual facilities to produce energy on-site and retain it for personal needs.
Energy producers are also able to sell the excess energy to the grid. Distributed energy storage solutions such as EVs, microgrids, and virtual power plants (VPPs) avert the expansion of coal, oil, and gas energy generation. Moreover, they enable greater reliance on renewables through the integration of local energy storage solutions like rooftop solar panels and small wind turbines.
MET3R advances Vehicle-to-Grid (V2G) Management
Belgian startup MET3R aids V2G management. The startup’s platforms, ZenCharge, ZenSite, and ZenGrid, utilize artificial intelligence (AI) to optimize fleet charging and reduce grid impact due to the charging site. Moreover, they provide insights on managing loads related to EV charging. Energy distribution companies leverage the startup’s platform to monitor the status of distributed energy assets (DERs) on low-voltage networks.
Karit provides Virtual Power Plants
Australian startup Karit offers virtual power plants. The startup combines a number of distributed energy assets such as generation and storage systems into a VPP. By consolidating the distributed energy assets, energy retailers ensure efficient power supply to customers while moving surplus energy into the market. Energy retailers and multi-site organizations use VPPs to enable predictive energy storage and management.
8. Solid-State Batteries
Conventional liquid electrolytes are highly combustible and have low charge retention and operational inefficiencies in extreme temperatures. To address these challenges, solid-state batteries replace the flammable liquid electrolyte with a solid compound that facilitates ion migration. Startups now use electrolytes like polymers and organic compounds that offer high ionic conductivity.
Additionally, solid electrolytes support the use of high voltage high capacity materials for battery manufacturing. This enables greater energy density, portability, and shelf life. Since solid-state batteries offer a greater power-to-weight ratio, they are also an ideal choice for use in EVs.
Solid State Battery (SSB) Incorporated makes Polymer-based Solid-State Electrolytes
SSB Incorporated is a US-based startup that makes polymer-based solid-state electrolyte material. The startup’s solid electrolyte combines polymer and ionic materials to improve ion mobility. In comparison with conventional liquid electrolytes, this material has high energy density while improving electrochemical and thermal stability. The solid-state separator allows packaging of these electrolytes into lithium batteries and also in larger applications such as vehicles or planes.
Theion is a German startup that devises solid-state crystal sulfur batteries. The startup uses direct crystal imprinting (DCi) to develop wafers from molten sulfur. Its proprietary solid-state polymer electrolyte operates within the voids of these wafers where lithium metal foil acts as an anode.
The advantages of this solution over conventional batteries include long cycle life, fast charging, low cell cost, and safety. Theion’s technology finds use in solutions ranging from smartphones and computer batteries to energy storage in cars and airplanes.
9. Hydrogen Storage
Hydrogen exhibits the highest heating value per mass of all chemical fuels while also being regenerative and environmentally friendly. It is stored physically either as gas or liquid. Storage as a gas typically requires high-pressure tanks whereas liquid storage requires cryogenic temperatures.
To economically store hydrogen, startups are designing innovative processes and storage tanks. In terms of storage types, recent trends indicate a shift towards the adsorption of hydrogen on solid surfaces and through chemical reactions. The applications of hydrogen storage range from use in cars as a clean fuel to portable power supply for buildings.
Swiss startup GRZ Technologies manufactures solid-state hydrogen storage systems. The startup stores hydrogen in atomic form within a metallic structure. This ensures greater safety while providing high volumetric density and a longer lifetime. The standardized stacks enable desirable storage capacity for obtaining stationary and portable power for the transportation industry.
Hydrogen First designs Composite Hydrogen Pressure Vessels
Hydrogen First is a Polish startup that designs composite overwrapped hydrogen pressure vessels. The flat vessel has an isotensoid shape with reinforcement studs across its thickness to store the compressed hydrogen. Its design facilitates carbon fiber reduction, thereby reducing the weight and cost of hydrogen storage. These flat composite containers find applications in the aerospace and automotive industry for storing hydrogen in gaseous, liquefied, supercritical, or cryogenic forms.
10. Energy Storage as a Service
There are several setup costs associated with the installation of energy storage infrastructure and long-term ownership leads to locked-in capital and stranded assets. Energy storage as a service allows businesses to obtain a reliable power supply at zero asset investment and low implementation costs. It enables facilities to evaluate the value of an energy storage solution.
This approach also offers maximum flexibility when market conditions shift. Further, energy storage as a service aids utilities in congestion management, seasonal peak demand management, and tackling grid infrastructure failures. Moreover, consumers in remote locations with weak or no grid connection benefit from increased grid flexibility and efficiency.
Hybrid Greentech simplifies Energy Storage Management
Danish startup Hybrid Greentech offers HERA, an AI-based energy storage management platform. It combines longer-term optimization models and short-term machine learning models to decide the optimal operation of energy storage assets.
This enables detailed operating expenses (OPEX) modeling in early concept development to ensure the best investment decisions. A variety of industries such as hybrid power plants, micro-grid, and electric mobility companies leverage this technology for advanced energy storage analytics.
Renon India makes Smart Battery Management Systems (BMS)
Renon India is an Indian startup that develops ARK, a smart battery management system. It performs passive balancing of cells by voltage measurement and temperature sensing. This ensures functional safety, efficiency, and performance of the battery packs. These ARK systems are suitable for batteries storing solar energy in commercial and industrial applications.
Discover all Energy Storage Trends, Technologies & Startups
Energy storage companies utilize advances in the sector to increase storage capacity, efficiency, and quality. Long-duration energy storage such as BESS plays a vital role in energy system flexibility. Battery energy management systems and VPPs, on the other hand, impact transmission and distribution grids. Additionally, standardization in storage systems, along with a network of distributed energy sources, will ultimately tackle challenges due to increasing energy demands and energy transition.
The Energy Storage Trends & Startups outlined in this report only scratch the surface of trends that we identified during our data-driven innovation and startup scouting process. Among others, lithium alternatives, hydrogen economy, and supercapacitors will transform the sector as we know it today. Identifying new opportunities and emerging technologies to implement into your business goes a long way in gaining a competitive advantage. Get in touch to easily and exhaustively scout startups, technologies & trends that matter to you!
By Joseph Webster and William Tobin View the original article here
Long-haul trucking is a highly promising use case for the US hydrogen industry, and California and Texas are two large potential markets for pioneering hydrogen-fueled trucking. Both states have excellent green hydrogen potential and are taking initial steps to become hydrogen trucking hubs. When it comes to decarbonizing heavy-duty transportation, hydrogen is here for the long-haul.
Cleaning up hydrogen
Today, the vast majority of hydrogen is produced from reforming the methane in coal or natural gas in a process that produces ten times more carbon dioxide than hydrogen by mass. It is principally used for refining heavy sour oil and producing ammonia for fertilizer.
The most promising pathways to create zero-carbon clean hydrogen at scale are through renewables-produced green hydrogen or nuclear-powered pink hydrogen, both of which use zero-carbon electricity to separate hydrogen and oxygen via electrolysis. There is also blue hydrogen, which comes from natural gas in a process paired with carbon capture. Blue hydrogen’s role in decarbonization, however, is contingent on the mass buildout of carbon transportation and storage infrastructure.
If deployed judiciously, clean hydrogen can have a meaningful impact on lowering emissions in hard-to-electrify sectors, which require a chemical feedstock, long-duration energy storage, or extreme heat.
Long-haul trucking is a viable clean hydrogen offtaker
For most forms of transportation, growing economies of scale have given batteries an edge over hydrogen fuel cells. However, long-haul trucking—which accounts for 7 percent of transportation emissions—may be too high a fence for batteries to climb.
As a vehicle becomes heavier, its battery must expand proportionately in volume to provide the requisite power. Electric freight tractors use battery packs that are significantly heavier than the weight of diesel a truck typically carries, which decreases range and payload capacity while requiring more frequent charging. This is meaningful in the freight industry, where time is precious, and downtime can come at a cost of over $50 per hour before accounting for costs of charging. An electric long-haul truck takes thirty minutes to charge to only 70 percent capacity even with megawatt charging. In comparison, hydrogen re-fueling can be done quickly. Refueling a hydrogen truck takes ten minutes.
Hydrogen fuel cell trucks are therefore likely to edge out batteries for trips surpassing 180 miles and payloads above 24,000 pounds, according to an industry study.
The US Department of Energy estimates that total cost of ownership for hydrogen fuel cell long-haul vehicles will become affordable by 2030 thanks to new production tax credits for clean hydrogen. Furthermore, the department cites evidence that the long-haul trucking sector is willing to pay a premium for clean hydrogen. This outcome, however, is contingent on a buildout of refueling infrastructure along freight corridors. To boost demand, infrastructure could be built along freight lines that support high volumes of freight, such as near seaports. This can help medium-sized refueling stations reach their breakeven utilization rate. To do so, industry and policymakers must overcome a chicken-and-egg problem. The development of refueling infrastructure is critical to enable hydrogen-powered long-haul trucks, and—conversely—hydrogen refueling stations will rely on long-haul trucking for their income, as hydrogen uptake in transportation is likely to be confined to this sector.
California and Texas: Unlikely hydrogen trucking partners
California and Texas are important players in both green hydrogen and long-haul trucking.
Not only do the two states have the largest populations and economies in the country, but they also have outstanding green hydrogen potential.
Both California and Texas have excellent renewable resources, including solar and wind. The two states have deployed nearly 74 gigawatts of solar and wind capacity with another 36 GW in development.
Texas and California are the nation’s largest and second-largest renewables generators. As more renewable electricity production grows in these states, so will green hydrogen capacity—although there will be tensions between providing renewables for power generation or hydrogen.
Long-haul trucking is a natural use case for green hydrogen in both states. Texas and California are the country’s largest users of diesel for the transportation sector, consuming 633,000 barrels per day in 2021, or about 21 percent of total US diesel demand. Both states rely heavily on trucking to transport cargo from ports along the coast of California and Texas to destinations further inland. Indeed, Los Angeles, Long Beach, and Houston are the country’s first, second, and fifth-largest container ports by volume, respectively.
There is already evidence that Texas and California’s long-haul trucking sectors could see synergies between ports and green hydrogen production. California provides fiscal support for zero-emissions vehicles, plans to end the sale of fossil fuel-powered medium- and heavy-duty trucks by 2036, and continues to develop hydrogen refueling infrastructure. Tellingly, Hyundai Motor will soon operate thirty fuel cell electric trucks in California; Hyundai states this deployment will mark the largest commercial deployment of fuel cell electric trucks in the United States in the super-large vehicle class. In North Texas, Air Products and AES are teaming up to construct the country’s largest green hydrogen facility to service the trucking industry.
The trucking fleet is replaced very rapidly: the average lifespan of a super-large class truck is eight years, while the median truck on the road today is approximately six years old. In comparison, personal vehicles are replaced on average only every ten and a half years. Moreover, unlike the personal vehicle segment, most long-haul trucks are procured by fleet owners who pay very close attention to the total cost of ownership, not just the sticker price. If hydrogen-fuel trucks become more competitive than their diesel counterparts, there could be a relatively rapid adjustment.
Hydrogen: Here for the long-haul
Hydrogen’s technical and economic fundamentals are likely to improve as technology advances and the Inflation Reduction Act incentivizes investments in renewables. Owing to their renewables potential, large ports, and significant diesel demand, California and Texas are primed to lead the trucking market’s transformation. While trucking fleet turnover will take time, hydrogen appears poised to disrupt the US trucking market.
By: Steven Carlini, VP of Innovation and Data Center View the original article here
In the zero-carbon economy of the future, electricity will become the dominant energy but green hydrogen (and the fuels derived from it) will have a role to play as well. Making green hydrogen viable and abundant will take collaboration, effort, and investment.
Pieces that need to fall into place to make green hydrogen viable
Hydrogen definitely has a role to play in global decarbonization. In the decarbonized world of the future, electricity will become the dominant energy with a 60-70% share in 2050, biofuels will rise, dependence on fossil-based energy will significantly decrease and hydrogen will increase. I want to focus on green hydrogen – derived from water using electrolysis since it is the most promising. In my estimation, green hydrogen will rise between 3 – 10 times the 90 Mt of hydrogen used today by 2050. The 3X – 10X projection goes from a very conservative 270 Mt (3X) to an aggressive 900 Mt (10X). So why is there such a large gap if green hydrogen is the energy source needed for hard-to-abate applications? Mainly because there are 10 significant “pieces” of the puzzle that must come together to produce green hydrogen at the scale needed.
1) Renewable Generation Electricity Capacity – Green hydrogen must be derived through electrolysis which is highly energy intensive. For hydrogen to be green the process must be electrified using a sustainable source (hydro, wind, or solar). How much? The electricity required by 2050 for decarbonized electrification and green hydrogen production of 900 Mt (10X) is estimated to be 130,000 TWh – around 5X today’s total electrical supply of 27,000 TWh. By 2050 using the 900 Mt (10X) green H2 assumption, 30% of electricity use will be dedicated to producing clean hydrogen and its derivatives, such as e-ammonia and e-methanol.
2) Electrolyzer Capacity – Once there is sufficient renewable generation, the capacity of electrolyzer plants needs to match. According to Bloomberg NEF, today’s global electrolyzer capacity of 300 MW must grow to 3000 GW by 2050 to meet clean hydrogen demands of 900 Mt (10X). IEA estimates that every month from January 2030 onwards, three new hydrogen-based industrial plants must be built.
3) Total Cost of green hydrogen – Green hydrogen is fundamentally tied to the cost of renewable electricity, the cost of clean water, CapEx cost of electrolyzer plants, the efficiency of the electrolyzer plant, and finally the cost of storing and transporting the green hydrogen. Today, green hydrogen can cost around €2.5-€5/kg, making it significantly more expensive than the fossil fuel alternatives. Levelized prices need to fall to €1.5/kg by 2050 and possibly sub-€1/kg, to make it competitive with natural gas. However, there are incentives from governments around the world to bring the price down. In the US part of the Inflation Reduction Act created new provisions for clean hydrogen. Under the law, clean hydrogen plants in 2023 can receive a production tax credit up to $3 per kg of hydrogen, for the first 10 years of operation through 2032.
4) Electrolyzer cost – the total installed costs of a GW scale industrial electrolysis plant is currently around 1400 €/kW for Alkaline electrolyzer technology and 1800 €/kW for PEM electrolyzer technology. These need to drop at least 50% by 2050 for green hydrogen to be cost-competitive. However, CapEx improvement plans cannot be a tradeoff resulting in reduced electrolyzer efficiency or durability.
5) Electrolyzer efficiency – Today’s efficiency hovers around 50%. To meet the cost targets, the consensus in the industry is that efficiency needs to continuously improve and be at 75% by 2050. This is a major engineering challenge, plus there is efficiency degradation every year as well.
6) Water Supply – Fresh or clean water must be used in electrolysis. Ocean or salt water (sometimes called seawater) cannot be used. Clean water can be aggregated from collecting rainwater or from a process called desalination. Desalination using reverse osmosis is another very energy-intensive process that also outputs brine (salt-dense water) as a byproduct.
7) Storage – Ideally, electrolysis plants should be located in areas that have abundant renewable electrical power and fresh water. Consumption in the future will likely be places like marinas for ships/vessels and airports for long-haul planes as well as strategic places in the electrical distribution system at the turbine or areas requiring grid stabilization. This means compression, storage, and transportation will be needed. Hydrogen does not degrade over time and can be stored indefinitely. In a gaseous form, it can be stored in ways: pressurized steel tanks and underground reservoirs or salt caverns (for large capacity). Hydrogen can also be liquefied. This would deliver about 75% higher energy density than gaseous hydrogen (stored at 700 bar), But it would waste the equivalent of 25%-30% of the energy contained in the hydrogen to liquefy.
8) Transportation Grid – Moving gaseous hydrogen from the place where it is derived to the place where it will be used is not a straightforward process. There is no piping infrastructure like there is with oil and natural gas pipelines or distribution grids. Because hydrogen is such a small and potentially combustible element, constructing a pipeline is quite challenging.
9) Demand side efficiencies – Just like miles per gallon affects how much fuel a car uses, all applications using electricity or hydrogen need to be made more efficient. A massive effort is required to modernize the existing stock of inefficient assets (buildings, mobility, industrial facilities, and machines, etc.), for higher efficiency or adapt to fun on hydrogen.
10) Funding – In total, investments could amount to almost $15 trillion between now and 2050 – peaking in the late 2030s at around $800 billion per annum1 for 900 Mt (10X). Of this, about $12.5 trillion (85%) relates to the required increase in electricity generation, with only 15% (peaking at almost $150 billion per annum in the late 2030s) relating to an investment in electrolyzer, production facilities, and transport and storage infrastructure. This investment must be coordinated between private-sector action and national and local governments.
The 10 “pieces” of the puzzle that must come together are significant. As with all puzzles, if a single piece is missing, the puzzle is ruined and the 3X scenario would be more likely than the 10X. We have no choice but to put this puzzle together and in this case, we must have all of the pieces in order to meet decarbonization targets and have green hydrogen play its critical role in the effort to halt global warming.
By: Felicity Bradstock View the original article here
There is great optimism around the future of green hydrogen, with many seeing it as a super-fuel that will replace oil-derived options, as well as be highly competitive with electric battery technology. However, we are far from achieving this ambition yet, mainly due to small-scale production operations and high costs. Many companies around the globe have plans to produce green hydrogen, but some are battling challenges that are slowing down the rollout of the clean fuel. Despite improvements in production processes, thanks to greater investment in the sector in recent years, the production and transportation costs of green hydrogen remain much higher than other fuels, including other types of hydrogen.
Producing grey or blue hydrogen, which is derived from fossil fuels, is viewed as relatively low cost, with many companies already relying on this fuel. Grey hydrogen is produced using natural gas. It undergoes a steam methane reforming (SMR) process, which breaks methane apart using high-pressure steam, which creates separate hydrogen, carbon monoxide, and carbon dioxide molecules. This process produces high levels of carbon dioxide, around 9 to 10 tons of CO2 for every ton of hydrogen. But it is also highly cost-effective, so long as natural gas prices remain stable. In July 2022, the cost of grey hydrogen was around $2 per kilo.
In contrast, green hydrogen production methods are more expensive. Green hydrogen is made using renewable energy sources to power an electrolysis process that separates hydrogen from water, producing just steam as a waste product. It is carbon neutral, making it highly attractive for companies looking to decarbonize. However, by July 2022, it cost around $4 to $5 a kilo, or even more, to produce green hydrogen. And some industry experts believe that the high cost of green hydrogen production isn’t going to fall any time soon.
Green hydrogen is viewed by many international agencies, such as the International Energy Agency (IEA) and the International Renewable Energy Agency (IRENA), as a solution to decarbonize ‘hard-to-abate’ sectors. As more governments and private companies around the globe pump funding into green hydrogen operations, there are high hopes that the production cost of green hydrogen to fall substantially, to as low as $0.5 per kilo. However, others believe it will be difficult to drive the cost to lower than $3 per kilo.
IRENA published two studies to drive green hydrogen production worldwide: Green Hydrogen: A Guide to Policy Making in November 2020, and Green Hydrogen Cost Reduction: Scaling up Electrolysers to Meet the 1.5°C climate goal in December 2020. These studies were aimed at encouraging governments and private companies to scale up production, aimed at driving down costs. However, the price of green hydrogen production so far remains elevated, at around 2 to 3 times the cost of grey hydrogen production, when gas prices are stable.
Nevertheless, progress has been seen thanks to greater funding into research and development, with the price of electrolysers falling by around 60 percent since 2010. According to IRENA, they could decrease by a further 40 percent in the short term and by as much as 80 percent in the long term. This cost reduction prediction relies on greater innovation in electrolysis technology to improve its performance, as well as scaling up manufacturing capacity, standardization, and growing economies of scale.
Another challenge to consider is the cost of transportation. Murray Douglas, the head of hydrogen research at Wood Mackenzie, stated that “Hydrogen is pretty expensive to move… “It’s more difficult to move than natural gas … technically, engineering wise … it’s just harder.” And Douglas is not the only one concerned about this. The U.S. Department of Energy (DoE) has reported challenges with green hydrogen including “reducing cost, increasing energy efficiency, maintaining hydrogen purity, and minimizing hydrogen leakage.” The DoE believes greater research is required to “analyze the trade-offs between the hydrogen production options and the hydrogen delivery options when considered together as a system.”
Companies worldwide are now considering the best locations for their green hydrogen production facilities. While there is great potential for the development of plants in Australia, North Africa, and the Middle East, these could be very far from their principal markets. Douglas highlighted the need for a dedicated pipeline, constructed between the producer and end-user if moving green hydrogen by pipe. Alternatively, green hydrogen could be transported as ammonia with nitrogen, which could be shipped and sold to consumers such as fertiliser producers. Otherwise, users would have to crack the ammonia back into nitrogen, which would increase costs and result in energy losses.
For green hydrogen to be as successful as everyone hopes, it will require significant investment to overcome these challenges. Jorgo Chatzimarkakis, the CEO of the industry association Hydrogen Europe, suggests the need for a certification system, to guarantee that any green hydrogen production was powered by renewable sources. Further, a well-researched delivery strategy needs to be developed to ensure that production facilities are adequately linked with green hydrogen markets. This has been seen in projects such as Cepsa’s green hydrogen corridor between southern and northern Europe.
While transportation costs are high, companies already understand how to move green hydrogen as they have been doing it the same way with natural gas for decades. But some are deterred by high costs. Therefore, the industry must drive down production costs to alleviate some of the pressure on transportation. Although the green hydrogen industry continues to face several major challenges, preventing a wide-scale deployment of the clean fuel, greater investment in the sector over the coming decades will likely fix many of these problems and allow for the deployment of global, large-scale green hydrogen production.
