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The recent cancellation of a Massachusetts networked geothermal project isn’t dampening enthusiasm for the emerging clean-heat strategy.
National Grid said this month it has abandoned a planned geothermal system in Lowell, Massachusetts, due to higher-than-expected costs. The news disappointed advocates who see networked geothermal as an important tool for transitioning from natural gas heat, but they pointed to many more reasons for optimism about the concept’s momentum.
The nation’s first utility-operated neighborhood geothermal network, a loop serving 36 buildings in the Massachusetts city of Framingham, is performing well and seeking to expand. It’ll soon be joined by a surge of pilot projects being developed across the country, testing different models and accelerating the learning curve. And a recent report forecasts as much as $5.2 billion in potential savings from leaning more heavily on geothermal energy than on air-source heat pumps.
“This is very promising,” said Ania Camargo, associate director of thermal networks for the Building Decarbonization Coalition. “Networked geothermal makes a lot of sense as a transition strategy.”
The idea for utility-operated networked geothermal systems, often also referred to as thermal energy networks, originated in Massachusetts. The concept grew out of conversations about the environmental and public health dangers posed by aging and increasingly leaky natural gas pipes.
In 2014, the state passed a law requiring gas companies to create plans to replace these leaky pipelines. These plans, however, are projected to cost nearly $42 billion to execute. Climate advocates began to question the wisdom of investing so much money in fossil fuel infrastructure when state policy was simultaneously pushing for electrification and renewable energy. At the same time, air-source heat pumps were catching on, a growing trend that would leave fewer and fewer gas consumers to foot the bill for pipeline repairs.
In 2017, Massachusetts clean energy transition nonprofit HEET proposed a solution: networked geothermal. The systems would be based on well-established geothermal technology, which circulates liquid through pipes that run deep into the ground, extracting thermal energy from the earth and carrying the heat back up to warm buildings. The same principle can provide cooling as well, transporting heat away from buildings and returning it to the ground.
Thermal energy networks scale up the process, connecting many buildings to one geothermal loop, allowing heating and cooling to be delivered to homes in much the same way gas and electricity are. At the same time, they offer a new business model for gas utilities grappling with states’ efforts to transition away from fossil fuels. Utilities liked the idea and jumped on board.
In 2023, the first two such systems broke ground in Massachusetts: National Grid launched one in Lowell, and Eversource began work on a system in Framingham.
The University of Massachusetts Lowell, which was a partner in National Grid’s now-canceled project, hopes to use the engineering and design work developed for the project as the basis for a future network, said Ruairi O’Mahony, senior executive director of the university’s Rist Institute for Sustainability and Energy.
Even the cancellation provides valuable insight by providing a case study of what didn’t work, said Audrey Schulman, executive director of HEETlabs, a climate solutions incubator that spun off from HEET. In this case, the problems included participating homes spread too far from each other and issues with the field where the boreholes were to be drilled. “We’re on an even better arc,” Schulman said. “If there’s a mistake made, we have to correct for it. We can’t have people paying for things that cost too much.”
Meanwhile, the Framingham network began hooking up its first customers in August 2024 and now has about 95% of its anticipated load up and running, said Eric Bosworth, clean technologies manager for Eversource. The system is performing well, keeping customers warm even when a recent cold snap dropped temperatures down to 6 degrees Fahrenheit, he said.
Plans are already underway to expand the system. The U.S. Department of Energy in December awarded Eversource, the city of Framingham, and HEET a $7.8 million grant to develop a second geothermal loop to be connected to the first network, in the process generating valuable information about expanding and interconnecting geothermal systems. The grant is still under negotiation with the federal agency, so it is unclear what the final terms will be. Still, Eversource hopes to have the second system installed in 2026.
“What we’re trying to prove out with Framingham 2.0 is, as we expand on an existing system, that we can do it more efficiently and bring down that cost per customer,” Bosworth said.
The widespread interest in networked geothermal systems within Massachusetts and throughout the U.S. is also promising, Camargo said. In Massachusetts, National Grid is continuing work on a different geothermal network pilot serving seven multifamily public housing buildings in the Boston neighborhood of Dorchester. Last year, HEET, with support from the Massachusetts Clean Energy Center, awarded $450,000 in grants to 13 communities to conduct geothermal feasibility studies. And a climate law passed in Massachusetts last year authorizes utilities to undertake networked geothermal projects without getting specific regulatory approval to veer out of their natural-gas lane.
New York has also embraced the idea with enthusiasm. In 2022, the state enacted a law allowing utilities to develop geothermal networks and requiring regulators to come up with guidelines for these new systems. So far, 11 projects have been proposed using a variety of approaches that will provide takeaways for the developers of future geothermal networks, Camargo said.
“New York is amazing,” she said. “They’re doing things in different ways to innovate.”
Across the country, between 22 and 27 geothermal networks have been proposed to utility commissions in Colorado, Maryland, Minnesota, and other states, she said. Eight states have passed legislation supporting utility construction of thermal energy networks, according to Building Decarbonization Coalition numbers, and another four or five are expected to file bills this year, Camargo said.
A report prepared by Synapse Energy Economics for HEETlabs and released last month concludes that geothermal networks offer significant financial benefits when compared with using air-source heat pumps. The analysis found that each system roughly the size of the Framingham network could generate from $1.5 million to $3.5 million in economic benefits, including avoided transmission and distribution costs from lowering peak demand. If 1,500 geothermal networks came online in Massachusetts, the savings could hit $5.2 billion, the analysis calculates.
These savings could be used to subsidize building retrofits, making the homes and offices connected to a geothermal network highly energy efficient to optimize the impact of the ground-source heat pumps, Schulman said.
Even with gathering momentum, challenges remain to the widespread adoption of geothermal networks.
Retrofitting buildings on the network is perhaps the thorniest, particularly in the Northeast where much of the building stock is older and draftier, said both utilities and advocates. In Framingham, an individual efficiency plan had to be created for each home and structure on the loop, a time- and money-consuming process. Going forward, a more streamlined, standardized procedure will likely be necessary, Camargo and Bosworth both said.
“Utilities have not traditionally worked inside the building, so who does it and who pays for it is something that still needs to get worked out,” Camargo said.
Cost is another concern, as the terminated Lowell project demonstrates. However, costs are likely to come down as engineers and installers gain experience in the process and develop smoother supply chains, Schulman said. The second loop planned for Framingham is already likely to be half the amount of the initial system, she said.
As these challenges are worked through, it is vital for Massachusetts to approach its role as a leader in geothermal networks with care, Schulman said.
“We need to think ahead and do this in an efficient and thoughtful way and show the country how it can be done,” she said.
The city of Minneapolis is retooling a decade-old partnership with its gas and electric utilities in response to criticism that it hasn’t done enough to help the city reach its climate goals.
The Clean Energy Partnership was established in 2014 as part of the city’s last round of utility franchise agreements with Xcel Energy and CenterPoint Energy. The agreements authorize utilities’ use of public right-of-way, often in exchange for fees or meeting other terms or conditions from the city.
A little over a decade ago, Minneapolis was among the first U.S. cities to view utility franchise agreements as a potential tool to leverage for climate action. Some advocates at the time had been pressuring the city to study creating a municipal utility to accelerate clean energy, and the partnership emerged as a compromise to give the city more say in the utilities’ operations.
Former City Council member Cam Gordon, who represented southeast Minneapolis in 2014 when the council approved the partnership, is one of the critics who say the initiative “never realized its potential.” Instead, it mainly served as “a government relations and promotional PR tool to allow [elected officials] and the utilities to feel like we’re doing something,” he said.
The City Council is set to approve new franchise agreements this week, and they include an updated memorandum of understanding for the Clean Energy Partnership that will require regular reporting on key performance indicators, new utility-specific emission goals, energy conservation, and service reliability in disadvantaged neighborhoods.
Spokespeople for both companies said they welcome the planned changes and that the agreement reflects their interest in working with city leaders on shared clean energy goals.
Since the partnership went into effect in 2015, it has brought together representatives of the utilities, the City Council, and the mayor’s office once per quarter to talk about efforts to reduce emissions in the city. Clean energy advocates and other stakeholders sit on an advisory committee but do not have a formal seat on the partnership’s governing board.
Minneapolis City Council Vice President Aisha Chughtai, who represents the council on the partnership board, expressed frustration about the lack of follow-through from utilities. “Sitting in a meeting and nodding along is one thing. Changing your actions is another,” she said.
By the partnership’s own measures, it has failed to make significant progress on five out of the city’s seven major climate goals. The city is on track with its target to eliminate greenhouse gas emissions from municipal operations but behind pace with its goals related to citywide, residential, commercial, or industrial emissions.
Going forward, the partnership board will continue to meet quarterly, but instead of revolving around city climate goals, each utility will be expected to hit specific targets within Minneapolis’s borders. CenterPoint will commit to reducing emissions from natural gas use by at least 20% by 2035 compared with 2021.
“I think it’s progress,” said council member Katie Cashman, who represents an area west of downtown. The gas utility’s target is “a very meager, insufficient goal, but it is a goal nonetheless, and they haven’t done this in any other city.”
CenterPoint agreed to send a more senior executive to attend the quarterly partnership meetings, though Xcel did not. The utilities also rejected the city’s proposal to hire an outside administrator to manage the partnership.
City leaders believe the new agreement does a better job of setting expectations, but Minneapolis will still lack formal leverage over the utilities if they fail to make progress. The agreement does not contain any penalties for failure to follow through, and the next window to renegotiate isn’t until 2035 when the franchise agreement comes back up for renewal.
Luke Hollenkamp, the city’s sustainability program coordinator, said data reported through the partnership allows the city to make course corrections in its climate work.
“We can see what’s working, what’s not working, and also see where we need to invest more time,” he said.
Xcel Energy’s spokesperson said the partnership has led to successes, noting that citywide emissions from electricity have declined and that Minneapolis met its goal of powering city operations with 100% renewable electricity in 2023 by participating in Xcel’s Renewable*Connect program.
CenterPoint said it has invested nearly $61 million in energy efficiency programs in Minneapolis since 2017, saving residents $25 million in energy costs while reducing 245,000 metric tons of emissions. The utility also developed an on-bill financing program advocated by clean energy activists and others.
Despite the partnership’s imperfections, current and former city officials said it’s better to keep it in place as part of the new franchise agreements than to let it dissolve.
“We’re ramping up our trajectory [to cut emissions],” Cashman said. “We’re setting an example of how other cities can lead on climate action.”
The City Council’s climate and infrastructure committee approved the new agreements on Feb. 6; the full council is set to vote on them Feb. 13.
Clean energy installations in the U.S. reached a record high last year, with the country adding 47% more capacity than in 2023, according to new research by energy data firm Cleanview.
Boosted by tax credits under the Inflation Reduction Act and the plummeting costs of renewable technologies, developers added 48.2 gigawatts of utility-scale solar, wind, and battery storage capacity in 2024. In total, carbon-free sources including nuclear accounted for 95% of new power capacity built in the U.S. last year; solar and batteries alone made up 83%.
The report finds that developers are not only building more projects but bigger ones, too. In 2024, companies built 135 solar, wind, and storage facilities with 100 megawatts or more of capacity, continuing a trend of clean energy megaprojects around the country.
Despite the growth of renewables, fossil fuels — mostly gas — still generated more than half of the U.S.’s electricity last year. Carbon-free sources including nuclear produced just over 40% of power.
This year, renewables will continue growing but at a slower pace, the report says. Based on developer projections, the U.S. could add 60 GW of large-scale clean power capacity in 2025. That would be a 26% jump from the previous year, but it’s only possible if the industry can maintain momentum despite headwinds from the Trump administration.
Solar led the way last year and is expected to do the same this year.
In 2024, the U.S. added a new record of 32.1 GW worth of utility-scale solar capacity. That’s a 65% increase from 2023, when the country added 19.5 GW of utility-scale solar. Most new solar was built in Texas, which added 8.9 GW worth of the clean energy source, followed by Florida, which built 3 GW and outpaced California for the first time. Arkansas, Missouri, and Louisiana each saw rapid growth in solar, adding hundreds of MW of capacity where relatively little existed before.
Developers expect to add 33 GW of utility-scale solar to the grid in 2025, which would represent a 3% year-on-year growth, the report finds. The U.S. Energy Information Administration, meanwhile, said in late January that it expects solar installations to decline to 26 GW this year.
Continued progress for solar — and for any clean energy deployments — will depend heavily on the Trump administration.
President Donald Trump has already stalled clean energy and infrastructure projects nationwide by attempting to halt hundreds of billions of dollars in congressionally authorized funding — a move that experts say is illegal and has been struck down by federal courts. Some Republican members of Congress have also threatened to roll back clean energy tax credits under the Inflation Reduction Act that are key to enduring growth in the renewables sector.
For utility-scale solar, “uncertainty around the Trump administration’s energy agenda and the future of the IRA will cause the segment to stagnate, despite extremely high demand from data centers,” analysts at Wood Mackenzie wrote in January.
The political picture is even more grim for the U.S. wind sector, which has already seen years of declining installations and now faces relentless attacks from Trump.
For several years now, the wind industry has faced challenges including a lack of long-distance transmission lines to transport electricity from far-flung areas in the middle of the country to urban centers. Supply chain woes and inflation have also led to a spate of canceled offshore wind projects in the Northeast.
In 2024, the U.S. added 5.1 GW of utility-scale wind, including its first commercial offshore wind farm, marking a 23% drop from 2023 and the fourth year in a row of falling annual installations. Texas alone accounted for 42% of the country’s new wind capacity in 2024, bringing 2.1 GW online.
Developers expect to add 9.2 GW of wind capacity this year, and 6.1 GW are already under construction or waiting to come online, according to the Cleanview report. If that happens, wind capacity additions would increase by 79% this year.
But that’s a big if. Trump has vowed that “no new windmills” will be built during his presidency and has taken aim at offshore wind in particular — a sector that on paper is set to give wind installations a big boost this year. It remains to be seen whether these under-construction projects will be able to forge ahead as planned despite political headwinds.
Battery storage could be more of a bright spot. Its growth, already fast, is set to accelerate this year.
Last year, the U.S. added 10.9 GW of battery storage capacity, a 65% year-on-year increase that surpassed the previous 56% leap in 2023. California and Texas brought the most grid storage online, building 3,152 MW and 2,832 MW of capacity respectively.
In 2025, storage developers expect to add 18.1 GW of capacity, which would equal a 68% jump from 2024. Based on projections, Texas will overtake California as the nation’s leading energy storage market by adding 7 GW of capacity this year, Cleanview found.
The battery buildout has been propelled in part by declining prices, but even energy storage hasn’t escaped Trump’s assault on renewables. The administration’s tariffs on Chinese imports are expected to negatively impact the industry, which relies on batteries manufactured in China.
As the Trump administration attempts to block billions of dollars in federal funds for electric vehicle charging, an Illinois utility is moving forward with a massive investment to promote wider EV adoption.
At a press conference last Thursday ahead of the 2025 Chicago Auto Show, ComEd announced $100 million in new rebates designed to boost EV fleet purchases and charging stations across northern Illinois. The program helps meet the mandate for the state’s Climate and Equitable Jobs Act, which calls for 1 million EVs on the roads by 2030.
Of the $100 million, $53 million is available for business and public-sector EV fleet purchases, while nearly $38 million is designated to upgrade infrastructure for non-residential charger installations. An additional nearly $9 million is intended for residential charging stations.
The money is in addition to $87 million announced last year for similar incentives.
Funding for the rebate programs comes from distribution charges and “has nothing to do” with the federal government, Melissa Washington, senior vice president of customer operations and strategic initiatives at ComEd, said during an interview. This means that there is no risk of withholding or reductions from the Trump administration.
Washington anticipates continued high levels of interest and engagement in the programs.
“Based upon what we saw last year, there was a quick demand. Applications came right away the minute we opened it up. I would imagine people will be going on [ComEd’s website] and immediately trying to see what we have available for them,” Washington said.
Since launching its EV rebate program last year, ComEd has funded projects in more than 300 ZIP codes, including nearly 3,500 residential and commercial charging ports, and provided funding for municipalities, businesses, and school districts to purchase more than 200 new and pre-owned EV fleet vehicles. The utility designated more than half the available rebate funds for low-income customers and projects in environmental justice communities.
ComEd also partners with the Chicago-area Metropolitan Mayors Caucus on the EV Readiness Program, which helps local governments create ordinances and safety and infrastructure plans to accommodate the growing demand for EVs in their communities. Since its initiation, more than 41 northern Illinois municipalities have participated in the program.
The importance of utility funding for the rebate programs was highlighted by Susan Mudd, senior policy advocate for the Environmental Law and Policy Center, who noted that a St. Louis-area school district is still waiting on 21 electric school buses that had been promised and ordered. The district has been unable to access the online portal to receive its federal funding, due to an executive order issued by the Trump administration.
“During the last four years, the federal government was a reliable partner with policies and programs that helped propel electric vehicle production and implementation and updated standards to save consumers money while cleaning up the air,” Mudd said at the press conference. “That order has already meant that students who would already be riding quiet zero-emission buses are still on old, dirty diesel ones, and the business that was to deliver them can’t get paid.
“While the new administration is willing to sacrifice the health of people across the U.S. and the world, thankfully, we in Illinois can continue to improve things,” Mudd said.
Canary Media’s Electrified Life column shares real-world tales, tips, and insights to demystify what individuals can do to shift their homes and lives to clean electric power.
Andrew Garberson isn’t worried about his electric vehicle handling cold winters.
He recently drove his EV to the gym when the temperature where he lives in Des Moines, Iowa, was a biting 4 degrees Fahrenheit. A polar vortex had brought a brutal wind, “the kind that whistles in the cracks of the car doors when you drive.”
Garberson relies on his electric truck, a graphite-gray Rivian, for year-round family road trips to see his parents, who live a few hours away. “My car will drive 200 miles in freezing conditions in the Midwest,” said the head of growth and research at Recurrent, a company that aggregates data on battery health from more than 29,000 EVs across the United States.
Switching from a gas car to an EV is one the biggest actions an individual can take to reduce their emissions. But EVs have gotten something of a bad rep in cold weather. It’s true that they, like gas cars, lose range as temperatures fall: Depending on the EV, the drop can be 16% to 46%. That loss may be anxiety-provoking, especially for EV owners-to-be.
From Garberson’s perspective, the criticisms are overblown. EVs work even in the most bone-chilling climates across the continental U.S., he said. In any case, Recurrent has found that knowledge and experience go a long way toward relieving those fears.
Plenty of frosty regions are embracing electric cars. Just look at Chicago. Despite its freezing winters, it’s one of the top cities for EV registrations, with more than 25,000 in the 12 months ending in June 2024, according to Experian’s most recent available data. Outside the U.S., the trend holds, too: In Norway, where temperatures can drop below -4˚F, nearly 9 out of 10 new cars sold in 2024 were fully electric.
In this article, we’ll dive into how to get the most winter range out of an EV. First up is a key EV feature to look for if you’re still shopping. Then, for those who already have an electric car, Garberson shares his top range-extending strategies.
EV range shrinks in the cold partly because the chemical reaction in their massive lithium-ion batteries slows down. But the biggest reason for winter range decline is the need to keep passengers warm, Garberson said.
Gas cars use the waste heat generated from the internal combustion engine for cabin heating. EVs don’t have an engine (they have a motor), so they don’t produce enough accidental heat to keep occupants cozy in frigid weather. Instead, EVs siphon energy from the battery to heat the cab, leaving less for propulsion. EVs can either make heat with an electric-resistance heater, which is like turning on a toaster, or much more efficiently move heat from the outdoors into the car using a heat pump.
Heat pumps are famous for their critical role in decarbonizing space heating in buildings. They don’t burn fossil fuel, and they’re typically two to three times as efficient as gas and electric-resistance systems, even below freezing. But the tech has also made its way into clothes dryers and water heaters. Now found in some EVs, heat pumps improve range by 8% to 10% in cold conditions, according to Recurrent.
According to Recurrent’s analysis, electric vehicles with the best winter range tend to have heat pumps, including the Tesla Models X, S, 3, and Y; Audi e-tron; and Hyundai Ioniq 5 and Kona.
It’s worth pointing out that heat pumps themselves are less effective as temperatures drop. Even so, EVs with heat pumps offer better range than those with electric-resistance heating. Recurrent points out that at 55˚F, a heat pump reduced range by 20% while a resistance heater lowered it by 33%. As the weather gets colder, the difference in range between EVs with heat pumps and those with resistance heaters shrinks.
To be clear, EVs work well in the winter even without heat pumps, Garberson said. His Rivian truck doesn’t have one, and on a day-to-day basis, he doesn’t even notice the decline in range. He charges at home, which makes topping up easy. For longer road trips, cold weather might mean he needs one more charging stop than he normally would.
Heating technology aside, drivers can take steps to get more out of their EVs in the cold. Recurrent’s Garberson offered his top three range-saving strategies for winter EV drivers.
Prewarm your EV while it’s plugged in. Garberson’s garage isn’t climate-controlled, so his vehicle gets chilly when the weather does. About 10 minutes before he hops in, he uses his car’s app to warm up the cabin. Pulling electricity from the wall outlet means he won’t have to use the battery to bring his car from 4˚F to a toasty 70°F.
Set your charging limit higher. Batteries are happiest when balanced at 50% charge, Garberson said. Because huge charge-level swings are harder on the battery, Recurrent recommends keeping it between 20% and 80% full. But “let’s eliminate anxiety from the discussion and just charge cars a bit more in cold conditions,” he advised. If you normally charge to 70% to keep the battery healthy, as Garberson does, increase it to 80% in the winter.
When you’re headed to a fast charger, set the destination in the car’s GPS, a feature in most modern EVs. Letting the EV know will allow it to start preconditioning the battery so it’s ready to charge when you get there. Otherwise, you may need to wait 15 to 20 minutes at the charger for the battery to warm up sufficiently, Garberson said. “It’s just amazing how [electric] vehicles have been designed over the last few years to help drivers without them even knowing.”
One more tip for your kit? Turning on the heated steering wheel and heated seats “is a far more efficient way” to warm yourself and passengers than heating up the air in the car’s cabin, Garberson said. Once the car is prewarmed and you’re on the road, you could dial down the thermostat and use the targeted heat features to keep you cozy.
But most importantly, Garberson added, do what you need in order to keep yourself and your passengers happy. He’s father to a one-year-old, so “relying on heated seats is not part of my driving equation.”
Besides, “I will admit I am kind of a sucker for creature comforts,” Garberson said. “I need heat any way I can get it.”
Manufacturers provide even more advice on how to extend the winter range of your particular EV model, so be sure to check out their online guides.
A little planning and know-how can go a long way toward a smooth EV experience in frosty weather, Garberson said. Winter takes a bite out of his EV’s range, yes, but “I get by just fine.”
Canary Media’s chart of the week translates crucial data about the clean energy transition into a visual format.
The amount of carbon-free energy built in the U.S. last year far eclipsed the growth of new fossil-fueled power plants.
The U.S. grid added a total of just over 56 gigawatts of power capacity last year. A whopping 96 percent of that came from solar, battery, wind, nuclear, and other carbon-free installations, per new Cleanview analysis of U.S. Energy Information Administration data.
Solar installations dominated power plant additions — 34 gigawatts of utility-scale solar were constructed across the U.S., a 74 percent jump from 2023’s record-high year. Texas and California drove most of this surge.
Grid batteries were the next-biggest new source of power capacity — and saw the fastest growth. The U.S. built 13 GW of energy storage last year, almost double 2023’s record-shattering 6.6 GW. Texas and California led the way here as well.
Wind was the third-biggest source of new capacity, but installations dropped for the fourth year in a row as the industry continued to struggle through lingering supply-chain issues, a plodding interconnection process, and local opposition to projects. Just 2.4 GW of new gas and 1 GW of nuclear went online in 2024.
The U.S. has rolled out more clean energy than fossil-fueled power plants for years now, helping the grid get cleaner and less carbon-intensive. Power emissions have fallen steadily since peaking in 2007 as fossil gas and renewables have replaced coal.
Still, fossil fuels generate the majority of the country’s power and the U.S. faces an uphill battle to decarbonize its grid by 2035, a goal set by outgoing President Joe Biden.
Fossil gas is currently the top source of electricity generation in the U.S., and last year emissions from its use in the rose nearly 4 percent. As big tech firms look to build more energy-intensive data centers to support their AI goals, the sector could become even more reliant on fossil fuels. That surging power demand is already extending the life of coal plants and causing utilities to propose building more gas-fired power plants.
In order to eliminate carbon emissions from the grid, the U.S. is going to need to figure out how to build enough clean energy to dethrone fossil fuels. That was a hard task even when Biden was president and before the AI-driven electricity boom took hold. It will be an even taller task under incoming President Donald Trump, who has vowed to double down on fossil fuels.
The Trump administration has declared that it is rescinding guidance for a $5 billion program that funds EV-charging installations nationwide, potentially halting states’ plans to put billions of obligated but as-yet unspent dollars to work. It’s the new administration’s latest attack on federal climate and clean energy programs authorized by Congress during the Biden administration, and like the others, it’s almost certain to be challenged in court, experts say.
The unexpected news came in a Thursday memo from the Federal Highway Administration to state transportation departments responsible for managing the National Electric Vehicle Infrastructure Formula Program. NEVI was created by the bipartisan infrastructure law passed by Congress in 2021 to establish reliable charging along major highways across the country. The program is structured to guarantee states access to funds under federally approved plans through fiscal year 2026.
The memo states that FHWA is “immediately suspending the approval” of these state plans pending a U.S. Department of Transportation review. States’ “reimbursement of existing obligations will be allowed in order to not disrupt current financial commitments,” the memo notes. But “no new obligations may occur” until new guidance is developed and states submit and receive approval for their updated plans — a process that could last through the rest of this year.
The memo’s instructions conflict with longstanding practice of guaranteeing states access to federal highway spending as well as with the structure of the NEVI program set by Congress in the infrastructure law.
“Freezing these EV charging funds is yet another one of the Trump administration’s unsound and illegal moves,” Katherine García, Sierra Club’s clean transportation for all director, said in a Friday statement. “This is an attack on bipartisan funding that Congress approved years ago and is driving investment and innovation in every state, with Texas as the largest beneficiary.” The Lone Star State is slated to receive nearly $408 million from the program.
Of the $5 billion authorized by NEVI, $3.27 billion has been obligated to all 50 states, Washington, D.C., and Puerto Rico, according to EV-charging data firm Paren. Of that, roughly $615 million is under contract for constructing almost 1,000 charging sites, Loren McDonald, Paren’s chief analyst, said in a webinar last month.
In a Thursday email, McDonald highlighted that “companies that are under contract with a state and have incurred expenses will get reimbursed.” At the same time, “the experts in Washington, D.C., that we have spoken to in the last few months believe that changes in NEVI like this would require a change in the law from Congress.”
“Our understanding is that FHWA does not have the authority to actually halt or revise the NEVI program this extensively, but will move forward, creating havoc for several months until lawsuits, the courts, and Congress resolve it,” he wrote.
Under the Biden administration, NEVI program formula funding was allocated through fiscal year 2026, and FHWA had approved states’ annual spending plans through fiscal year 2025, Kelsey Blongewicz, policy analyst at research firm Atlas Public Policy, told Canary Media last month.
That funding is “tied to approved state plans and contracts that makes it nearly impossible to reverse or stop,” Beth Hammon, senior EV infrastructure advocate at the Natural Resources Defense Council, wrote in a blog post last month.
Still, FHWA’s new instructions “create great uncertainty for the billions of dollars states and private companies are investing in the urgently needed infrastructure to support America’s highway transportation network,” Ryan Gallentine, managing director at Advanced Energy United, said in a Thursday statement. The trade group represents EV manufacturers, charging infrastructure developers, and other companies involved in NEVI-funded projects.
“States are under no obligation to stop these projects based solely on this announcement,” he wrote. “We call on state DOTs and program administrators to continue executing this program until new guidance is finalized.”
President Donald Trump attacked EVs and the NEVI program on the campaign trail. His administration issued an executive order within hours of his inauguration demanding a halt to all Biden-era climate and clean energy spending and singled out the NEVI program for scrutiny.
Federal agencies have since halted the flow of tens of billions of dollars of federal climate and clean energy funding, drawing outrage from state agencies, nonprofit groups, and companies that have been unable to recover money already spent on projects and programs. Two federal judges have responded to lawsuits challenging the freeze by issuing court orders demanding a halt to them, but a multitude of programs remain inaccessible, according to reports from grant recipients.
Confusion over the NEVI program’s future comes at a moment when significant investments are starting to flow from states to EV-charging manufacturers and charging-network providers — including Tesla — after years of bureaucratic and administrative delays. Federal data as of November tracked 126 operational public charging ports at 31 sites built using NEVI funding.
The Biden administration hoped to spur the buildout of 500,000 public charging stations by 2030, up from about 206,000 today. The NEVI program wasn’t intended to build all those chargers itself but to help install them in places where the economics of providing EV charging aren’t yet supported by the number of EVs on the road, McDonald said.
“In many states, the NEVI program helped jumpstart investment in high-speed EV charging stations, getting high-speed chargers at the gas stations and truck stops where millions of drivers already stop every year,” Ryan McKinnon, spokesperson for Charge Ahead Partnership, a trade group representing fueling-station owners and convenience store chains that make up the majority of NEVI charging sites, said in a Friday statement. “Other states dragged their feet.”
According to McDonald, since NEVI was singled out by the Trump administration, six states have indefinitely discontinued work on it, including Ohio, the Republican-led state that installed the program’s first live chargers in 2023.
UPDATE: In a Friday email, an FHWA spokesperson stated the agency is “utilizing the unique authority afforded under the NEVI Formula Program to ensure the Program operates efficiently and effectively and aligns with current U.S. DOT policies and priorities.”
Massachusetts’ attorney general says plans by the state’s major utilities to lower the cost of charging electric vehicles would offer little actual savings for customers.
In response to a 2022 Massachusetts climate law, the state’s two primary electric utilities, Eversource and National Grid, have proposed plans to create lower rates for charging EVs during off-peak hours, which they say would be implemented no sooner than 2029.
In a regulatory filing last week, however, the state’s attorney general said the utilities’ estimated savings for customers are based on faulty calculations and would be much lower in reality. Plus, a requirement that households and small businesses pay for additional meters to track their charging stations’ power use “negates all financial value for the customer.”
With this filing, the attorney general’s office joins climate advocates who support the idea of offering EV drivers the chance to save money by charging during off-peak hours but take issue with the way utilities propose to implement the strategy.
“If you require that people install a second meter and that they cover the cost of that installation, nobody’s going to do it,” said Anna Vanderspek, electric vehicle program director at the Green Energy Consumers Alliance.
Regulators have asked the utilities for feedback on the attorney general’s concerns and recommendations by February 20. A spokesperson for Eversource did not specifically address the attorney general’s criticism when asked about it but said the utility believes in the benefits of time-of-use pricing and looks forward to continuing the regulatory process. National Grid did not respond to a request for comment in time for publication.
More than a third of cars sold in the United States are likely to be EVs by 2030, J.D. Power forecasts, a prospect that has many industry and elected leaders wondering whether the country’s electric infrastructure is ready to provide power for this growing, gas-free fleet.
Massachusetts has set the ambitious target of putting 900,000 EVs on the road — and on the grid — by 2030. So, like other states facing the same challenges, Massachusetts has turned to the idea of using financial incentives to encourage EV owners to charge during off-peak hours and to lower the cost of charging for drivers in a state where electricity prices are among the highest in the country.
“Electric vehicle time-of-use rates could be a very valuable tool for helping to alleviate the load on the system as well as helping to incentivize people to think about when they’re using electricity,” said Priya Gandbhir, director of clean power at the Conservation Law Foundation.
In the 2022 climate law, legislators required utilities to propose these so-called time-of-use rates, which both Eversource and National Grid did in August 2023.
Eversource’s plan calls for a $15 monthly fee and an off-peak EV charging rate of 19 cents per kilowatt-hour, slightly more than half the proposed peak rate. National Grid would impose a $10 monthly fee and charge 14 cents per kilowatt-hour for off-peak charging, half what the peak rate would be. Both plans would require a separate meter, and both contend the rates cannot be implemented before advanced metering infrastructure is rolled out and tested, a process they expect to take at least four years.
Regulators must rule on these proposals by the end of October.
The numbers laid out by the utilities don’t add up to savings for consumers, the attorney general’s testimony argues. Thus, the proposals are unlikely to motivate more people to buy EVs or to shift their charging times.
The utilities did not estimate the cost of installing a separate meter, but online estimates run from $1,400 to more than $4,000. At the same time, the utilities drastically overstated the savings their plans would yield by using inflated estimates for how many kilowatt-hours the average driver would use to charge their EV, the attorney general’s testimony says. Rather than saving as much as $146 a month, as the utilities calculated, drivers would cut their bill by $21 per month at most, assuming they do all of their charging during off-peak hours. Customers who sometimes charge during peak hours could even see bill increases.
“The math just doesn’t work out,” Vanderspek said.
The attorney general’s office recommends that public utilities regulators reject National Grid and Eversource’s proposals and offers several alternative approaches. The simplest, the testimony says, would be to offer whole-home time-of-use rates, rather than separating out the vehicle charging load. Evidence from other states suggests such a rate could be implemented during the roll-out of advanced metering infrastructure, rather than waiting the minimum of four years the utilities say would be necessary for an EV-specific rate. The filing points to Colorado, where time-of-use rates are rolling out in concert with advanced metering infrastructure.
Another option would be to use data collected by vehicle computer systems or chargers themselves to issue rebates or apply lower rates for charging done at off-peak times. Utilities in California and Minnesota have already deployed this approach.
The same data could be used to offer other financial incentives. National Grid, in fact, already offers such a program in Massachusetts, giving customers 5 cents per kilowatt-hour for off-peak EV charging during the summer and 3 cents per kilowatt-hour the rest of the year.
Any of these approaches could be used not just to improve financial incentives for customers but also to speed up their implementation, to the benefit of both consumers and the environment, Vanderspek said.
“We’re all better off if we’re shifting that load off-peak right now,” she said.
Canary Media’s chart of the week translates crucial data about the clean energy transition into a visual format.
Nearly $2.1 trillion was invested in the global energy transition in 2024 — the highest-ever annual amount.
Last year’s total energy-transition investment was 11% higher than in 2023 and more than double what was spent in 2020, per BloombergNEF.
Most of this money is flowing to two energy-transition sectors: electrified transportation and clean energy.
More than $757 billion was invested in passenger and commercial EVs, electric two- and three-wheelers, and public EV-charging stations. That’s a 20% increase from 2023. Another $728 billion was spent on renewable energy projects ranging from wind to solar to hydropower, a record high but only about 8% more than in 2023. Energy-storage spending, meanwhile, surged 36% last year to nearly $54 billion.
The third-biggest category was power grids, which need to grow in every country to accommodate the rapid expansion of clean energy. Just over $390 billion was invested in 2024 on expanding and retooling grids across the world, up about 15% compared with the year prior.
While funding for these mature energy-transition technologies reached new heights in 2024, earlier-stage climate technologies had a rougher year. Spending on carbon capture and storage was less than half of what it was in 2023. Investment in hydrogen and clean-industry projects was also cut almost in half.
China alone accounted for nearly 40% of last year’s energy-transition investment, outpacing the U.S., EU, and U.K. combined. China also grew its spending faster than any other major country or region last year, while in the EU and the U.K., the sector attracted less money than in the prior year.
By a different measure, from the International Energy Agency, energy-transition investment is now far exceeding funding for fossil-fuel projects. That’s a good thing for the global bid to eliminate use of planet-warming fossil fuels. But even last year’s record-setting pace is not enough to decarbonize the planet. More is needed, the IEA says, especially in developing nations.
The U.S. solar energy industry has succeeded in doing something that would have been hard to imagine a few years ago: It has officially built more than enough factories to meet the country’s demand for solar panels.
The nation can now produce nearly 52 gigawatts of solar panels each year, per a new tally from the Solar Energy Industries Association. That’s up from the 40 GW of capacity reported in late 2024. These numbers don’t count actual production, which is subject to factors like staffing and market demand, but rather what the industry is capable of. Current capacity exceeds the module component of SEIA’s goal from 2020, which was for the whole solar supply chain to hit 50 GW by 2030.
The factory buildout employs workers across the U.S. in high-tech manufacturing roles and diminishes reliance on China, the long-time leader in solar manufacturing. But solar panels, which industry insiders refer to as modules, are just the last step of the solar supply chain: Currently, U.S. factories assemble modules from solar cells that are almost exclusively produced overseas. Those cells, which convert sunlight into electricity, incorporate wafers that are meticulously sliced from silicon ingots; factories that make ingots, wafers, or cells are more complex and capital-intensive than module assembly plants.
Those precursor steps have lagged behind the U.S. module buildout, but companies have pledged to build factories for 56 GW of solar-cell capacity in the next few years, SEIA said. Those proposed projects, if they get built, would meet the needs of the newly revitalized U.S. solar-panel industry. But erecting solar-cell factories requires a step change in capital investment compared with module assembly.
In November, legacy solar manufacturer Suniva kicked off the first new domestic cell production since U.S. producers (Suniva included) succumbed to competition from China in the 2010s. ES Foundry launched pilot cell production at its South Carolina plant in January. The company plans to employ around 500 workers by this summer and ramp up to 3 GW of annual production capacity by the end of September.
Five more cell factories are under construction, per SEIA. They include QCells’ complex in north Georgia, which should bring 3.3 GW of cell production online later this year, and Silfab Solar’s 1 GW plant in South Carolina.
But President Donald Trump swiftly attacked his predecessor’s investments in clean energy, signing an order on his first day in office to “immediately pause the disbursement of funds” from the Biden administration’s landmark climate and infrastructure laws. That order targets grants, loans, and other appropriated funds and therefore does not seem to affect tax credits, Canary Media previously reported. But the move has sown confusion in clean-energy markets and could presage attempts to undo the legislation that created the tax credits.
Some companies are thus holding back on solar-cell factory investments until they see what the Trump administration does with a key manufacturing tax credit, which has proven vital to secure construction loans.
The rebirth of U.S. solar manufacturing had to start somewhere, and assembling panels made sense as that first step. Now, all those panel makers could become anchor customers for the next link in the chain — the proposed cell manufacturers. But making that jump isn’t so easy.
Take the case of Heliene, a company based in Ontario, Canada, that nonetheless has established its bona fides as a committed U.S. solar manufacturer.
Heliene opened a solar-module factory in Mountain Iron, Minnesota, back in 2017, during the first Trump administration. The company later expanded that facility to assemble 800 megawatts of panels per year with a staff of 320 workers. Another expansion is already underway to grow that workforce to 520 and capacity to 1.3 GW by April.
In November, when previously bankrupt Suniva began the first U.S. cell production in years, Heliene swooped in to purchase every cell Suniva’s new factory could make. Heliene could, for the time being, tout its products as the only U.S.-built modules filled with U.S.-built cells.
Now Heliene is working on its boldest move yet: a $200 million solar-cell factory to be built somewhere in the U.S. in partnership with India’s Premier Energies. But Heliene founder and CEO Martin Pochtaruk told Canary Media in January that he couldn’t make the final call on that plant given the uncertainty around what will happen to Biden-era tax credits under Trump.
Building a cell factory requires a significant step up in dollars and complexity compared with a module-assembly plant, Pochtaruk explained. Putting panels together is a largely mechanical task that costs around $30 million of capital investment for every GW of production, he said.
Solar-cell production costs more than four times that, at about $130 million per GW, Pochtaruk noted. “It’s a chemical process that is much more complex. You need to build a clean room that is similar to an operating room, but industrial-sized.”
Cell production exposes silicon wafers to chemicals in liquid and gaseous forms, which must unfold in precisely calibrated environments, Pachtaruk added. Water used in the process requires treatment before it can be reused or sent to the sewer. The equipment to do all these things drives up costs relative to module assembly and makes permitting more complicated.
That raises the stakes for anyone looking to put their chips on the table for American solar-cell production — even if they’ve already found success in their panel-assembly bets. The prospects of financing these bigger bets are intimately tied to the future of federal manufacturing tax credits, part of the Biden policies that Trump has vowed to dismantle.
Even successful solar manufacturers typically don’t want to fork over their own cash for the hefty expense of a new cell factory. They turn to lenders to finance construction costs. But lenders have a hard time loaning money to a type of business without much of a track record to evaluate, and the current U.S. cell-manufacturing landscape is mostly nonexistent.
Cell manufacturers have something else going for them, though: the 45X tax credit. As enacted in the Inflation Reduction Act of 2022, 45X awards a set amount of money for each key solar component that a company makes in the country in a given year. If the manufacturer doesn’t have enough tax liability to absorb all that credit, it can sell the credits to another entity, generating cash to pay down debt or invest in further expansion.
Heliene pulled that off last fall with 45X credits from module production and netted about $50 million from the transaction.
Financial institutions mulling a $100 million–plus loan to a solar-cell manufacturer want to use the future 45X credit as collateral, Pochtaruk said. Future cell sales may be hard to predict, but a guaranteed payout based on the number of cells produced is easy to model (at least in a world where the U.S. government honors legally binding contracts and pays its obligations).
“Lenders will not agree to come forward until there’s clarity” on the long-term status of the tax credits, Pochtaruk said. So Heliene is still finalizing a location in the U.S., tabulating construction costs, and then will need to make a final call on the investment by late April. A Premier Energies executive told investors Monday that the plan is on pause pending clarity on the fate of the tax credits.
The potential loss of tax credits may be less consequential to companies like Qcells, which can draw construction funds from its corporate parent, Korea’s Hanwha. A smaller solar-focused company like Heliene doesn’t have other corporate coffers to rely on in lieu of tax-credit–based financing.
It’s still entirely possible that the credits will survive. Under normal circumstances, it would take a new act of Congress to undo them. A cadre of Republicans in Congress has publicly urged leadership to preserve them, based on the economic benefits they bring to their districts. Meanwhile, SEIA coordinated a lobbying push on Capitol Hill Wednesday to meet with more than 100 members of Congress or staff to urge them to protect the credits.
The current uncertainty, though, is at the very least delaying the commitment of more private funds to build solar-cell factories. Those projects — and the high-tech, well-paying manufacturing jobs they come with — could collapse altogether if the situation persists or Congress undoes the recently created tax credits.
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