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A new report from the American Council for an Energy-Efficient Economy has some exciting data for anyone attempting to retrofit a multifamily building.

By now there’s plenty of evidence showing why heat pumps are such a promising solution for getting buildings off fossil fuels. But most of that research has focused on single-family homes. Larger apartment buildings with steam or hot water heating systems — i.e. most of the apartment buildings in the Northeast — are more difficult and expensive to retrofit.
A new report from the nonprofit American Council for an Energy-Efficient Economy, however, assesses a handful of new technologies designed to make that transition easier and finds they have the potential to significantly lower the cost of decarbonizing large buildings.
“Several new options make decarbonizing existing commercial and multifamily buildings much more feasible than a few years ago,” Steven Nadel, ACEEE’s executive director and one of the authors, told me. “The best option may vary from building to building, but there are some exciting new options.”
To date, big, multifamily buildings have generally had two flavors of heat pumps to consider. They can install a large central heat pump system that delivers heating and cooling throughout the structure, or they can go with a series of “mini-split” systems designed to serve each apartment individually. (Yes, there are geothermal heat pumps, too, but those are often even more expensive and complicated to install, especially in urban areas.)
While these options have proven to work, they often require a fair amount of construction work, including upgrading electrical systems, mounting equipment on interior and exterior walls, and running new refrigerant lines throughout the building. That means they cost a lot more than a simple boiler replacement, and that the retrofit process can be disruptive to residents.
In 2022, the New York City Housing Authority launched a contest to try and solve these problems by challenging manufacturers to develop heat pumps that can sit in a window just like an air conditioner. New designs from the two winners, Gradient Comfort and Midea, are just starting to come to market. But another emerging solution, central air-to-water heat pumps, also presents an appealing alternative. These systems avoid major construction because they can integrate with existing radiators or baseboard heaters in buildings that currently use hot water boilers. Instead of burning natural gas or oil to produce hot water, the heat pump warms the water using electricity.
The ACEEE report takes the cost and performance data for these emerging solutions and compares it to results from mini-splits, central heat pumps, geothermal heat pumps, packaged terminal heat pumps — all-in-one devices that sit inside a sleeve in the wall, commonly used in hotels — and traditional boilers fed by biogas or biodiesel.
While data on the newer technologies is limited, so far the results are extremely promising. The report found that window heat pumps are the most cost-effective of the bunch to fully decarbonize large apartment buildings, with an average installation cost of $9,300 per apartment. That’s significantly higher than the estimated $1,200 per apartment cost of a new boiler, but much lower than the $14,000 to $20,000 per apartment price tag of the other heat pump variations, although air-to-water heat pumps came in second. The report also found that window heat pumps could turn out to be the cheapest to operate, with a life cycle cost of about $14,500, compared to $22,000 to $30,000 for boilers using biodiesel or biogas or other heat pump options.
As someone who has followed this industry for several years with a keen interest in new solutions for boiler-heated buildings in the Northeast — where I grew up and currently reside — I was especially wowed by how well the new window heat pumps have performed. New York City installed units from both Midea and Gradient in 24 public housing apartments, placing one in each bedroom and living room, and monitored the results for a full heating season.
Preliminary data shows the units performed swimmingly on every metric.
On ease of installation: It took a total of eight days for maintenance workers to install the units in all 24 apartments, compared to about 10 days per apartment when the Housing Authority put split heat pump systems in another building.
On performance: During the winter, while other apartments in the building were baking in 90-degree Fahrenheit heat from the steam system, the window unit-heated apartments maintained a comfortable 75 to 80 degree range, even as outdoor temperatures dropped to as low as 20 degrees.
On energy and cost: The window unit-heated apartments used a whopping 87% less energy than the rest of the building’s steam-heated apartments did, cutting energy costs per household in half.
On customer satisfaction: A survey of 72 residents returned overwhelmingly positive feedback, with 93% reporting that the temperature was “just right” and 100% reporting they were either “neutral” or “satisfied” with the new units.
The Housing Authority found that the units also lowered energy used for cooling in peak summer since they were more efficient than the older window ACs residents had been using. Next, the agency plans to expand the pilot to two full buildings before deploying the units across its portfolio. The pilot was so successful that utilities in Massachusetts, Vermont, and elsewhere are purchasing units to do their own testing.
The ACEEE report looked at a handful of air-to-water heat pump projects in New York and Massachusetts, as well, only two of which have been completed. The average installation cost per apartment was around $13,500, with each of the buildings retaining a natural gas boiler as a backup, but none had published performance data yet.
Air-to-water heat pumps have only recently come to market in the U.S. after having taken off in Europe, and they don’t yet fit seamlessly into the housing stock here. Existing technology can only heat water to 130 to 140 degrees, which is hot enough for the more efficient hot water radiators common in Europe but too cold for the U.S. market, where hot water systems are designed to carry 160- to 180-degree water, or even steam.
These heat pumps can still work in U.S. buildings, but they require either new radiators to be installed or supplemental heat from a conventional boiler or electric resistance unit. The other downside to an air-to-water system is that it can’t provide cooling unless the building is already equipped with compatible air conditioning units.
One strength of these systems over the window units, however, is that they don’t push costs onto tenants in buildings where the landlord has historically paid for heat. They also may be cheaper to operate than more traditional heat pump options, although data is still extremely limited and depends on the use of supplemental heat.
It’s probably too soon to draw any major conclusions about air-to-water systems, anyway, because new, potentially more effective options are on the way. In 2023, New York State launched a contest challenging manufacturers to develop new decarbonized heating solutions for large buildings. Among the finalists announced last year, six companies were developing heat pumps that could generate higher-temperature hot water and/or steam. One of them is now installing its first demonstration system in an apartment building in Harlem, and two others have similar demonstrations in the works.
The ACEEE report also mentions a few other promising new heat pump formats, such as an all-in-one wall-mounted heat pump from Italian company Ephoca. It’s similar to the window heat pump in that it’s contained in a single device rather than split into an indoor and outdoor unit, so it doesn’t require mounting anything to the outside of the building or worrying about refrigerant lines, although it does require drilling two six-inch holes in the wall for vents. These may be a good option for those whose windows won’t accommodate a window heat pump or who don’t like the aesthetics. New York State is also funding product development for better packaged terminal heat pumps that could slot into wall cavities occupied by less-efficient packaged terminal air conditioners and heat pumps today.
Gradient and Midea are not yet selling their cold-climate window heat pumps directly to consumers. Gradient brought a version of its technology for more moderate climates to market in 2023, which was only suitable for heating at outdoor temperatures of 40 degrees and higher. But the company has discontinued that model and is focusing on an “all-weather” version designed for cold climates, which is the one that has been installed in the New York City apartments. Gradient told me it is currently selling that model in bulk to multi-family building owners, utilities, and schools. Midea did not respond to my inquiry.
One big takeaway is that even the new school heat pumps designed to be easier and cheaper to install have higher capital costs than buying a boiler and air conditioners — a stubborn facet of many climate solutions, even when they save money in the long run. Canary Media previously reported that the Gradient product would start at $3,800 per unit and the Midea at $3,000. Experts expect the cost to come down as adoption and demand pick up, but the ACEEE report recommends that states develop incentives and financing to help with up-front costs.
“These are not just going to happen on their own. We do need some policy support for them,” Nadel said. In addition to incentives and building decarbonization standards, Nadel raised the idea of discounted electric rates for heat pump users, an idea that has started to gain traction among climate advocates that a few utilities have piloted.
“To oversimplify,” Nadel said, “in many jurisdictions, heat pumps subsidize other customers, and that probably needs to change if this is going to be viable.”
Editor’s note: This story has been updated to include comment from Gradient.
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Talking with SVP of strategy Sarah Jewett about the competition, expansion plans, and how to get more Americans informed and onboard.
Just three years ago, enthusiasm for geothermal energy was lukewarm at best. In a sign of just how marginal it seemed, the firehose of federal money directed at clean energy investments under the Biden administration contained just $84 million for geothermal, specifically for next-generation technologies. By contrast, the next-generation nuclear industry received roughly 40 times more.
Geothermal electricity generation uses heat from the Earth’s molten core to spin turbines that generate carbon-free, 24/7, renewable energy — a pretty attractive offer in today’s age of rampant climate change and soaring demand. Though the technology has been in use since 1913, it’s been stymied since then by the industry’s dependence on finding rare and unique underground reservoirs of hot water.
Then in 2023, a little-known startup backed by Bill Gates, among others, achieved a breakthrough at a pilot project in Nevada, showing that fracking technology could be used to harvest energy from hot, dry rocks, which can be found virtually anywhere in the world.
Fervo Energy’s announcement hit the geothermal industry’s smoldering embers like a splash of gasoline. Investors saw a reliable new source of carbon-free electricity that could tap into existing oil and gas supply chains and workforces and clamored to put their money into the startup, which had raised roughly $1.5 billion from private investors prior to the IPO. As the need for more energy to power data centers for artificial intelligence has grown, that interest has only intensified. Case in point: The company actually upsized its initial public offering on the Nasdaq stock exchange this week.
The money from the IPO, the company said in its initial filing with the Securities and Exchange Commission, would go to Fervo’s flagship installation at its debut 500-megawatt Cape Station plant in Utah. When all was said and done after the company’s Tuesday debut, it had netted nearly $1.9 billion — about 50% more than the initially planned $1.3 billion. When trading picked up again on Wednesday, the price soared more than 30%, to over $36 per share.
Late Wednesday afternoon, I spoke to Sarah Jewett, Fervo’s senior vice president of strategy, to discuss the IPO and what’s next for the company. The transcript of our conversation, conducted over Zoom, has been lightly edited for clarity and length.
Congratulations, Fervo has just made quite the stock market debut. Just a few days ago, the company upsized its initial public offering. Then yesterday, when the FRVO ticker officially launched at the Nasdaq, you ended up raising nearly $1.9 billion, beyond the $1.3 billion you initially anticipated. You must be feeling pretty good today.
I’m teeing you up for the pun here, Alexander: Geothermal is so hot right now. The IPO is not a finish line for Fervo. It is a financing milestone that facilitates the build out of more clean, firm, reliable, affordable energy. That is what we are most excited about as we ring the bell in Nasdaq. As we celebrate, we are more excited than anything to get back to work, to put clean megawatts in the grid.
Well then, let’s drill down on that. What were you seeing from investors before the IPO?
Investors, when we went around to sell, sell, sell , they were familiar with the need for energy. They were familiar with what’s happening in tech and AI. They were familiar with the existing solutions for power. They saw us as a new entrant into the scene that is highly capable of bearing the weight of resolving this intense energy crunch. Because of that, as we sold our story over the IPO roadshow, we just saw insane demand and decided it was the right idea to upsize the round.
Beyond the big player in conventional geothermal, Ormat Technologies, there haven’t really been many pure-play options in the retail market for people who want a piece of the action more broadly within geothermal. Where do you draw the line between where investors are buying into Fervo, specifically, and where they are buying into geothermal, generally?
These are really sophisticated investors. It’s overly reductive to say they’re just investing in us because we are a leading contender in an interesting industry to them. These are sophisticated investors who have vetted our technology, our performance, our execution to date, how we think about growth. They really bought into that story, specifically, as being a story that they believe to have real sustainability.
Where do you see the biggest potential competition? Do you think it will come from an incumbent player who makes a pivot into the next-generation market? Or do you think one of these other startups in the mix such as Sage Geosystems or XGS Energy or Quaise Energy could find similar success to Fervo?
We’re driving a rising tide that should lift all boats. I’m not going to publicly place bets on who I think will be the closest follower. But I’m hopeful that we will start to see more successful competitors in the years to come. The market that we’re addressing is massive right now. Because of that, we should see enhanced competition going forward. In some ways, we would be disappointed if that weren’t the case. We have developed a technological solution that is really meaningful. It should encourage others to come try to do the same.
Fervo is really differentiated in the years of execution that we have under our belt. At this point in time, we’ve drilled 40 horizontal geothermal wells. That is a huge differentiating factor at this point in time. The demand is here now. We are well positioned to meet that demand in a way that is rapidly scalable. We are in the right place at the right time.
We like to say internally that, coming to this point, we didn’t have to contend with Fervo. Now competitors will have to contend with Fervo. We obviously believe in the geothermal energy industry, which is why we’ve been so public with publishing our data and talking about what we’re trying to do. But we do really think that we have a substantial lead on the market, just in execution. And then, of course, we have immense amounts of IP and data and learnings to go with it.
Do you plan for the primary business to remain electricity production? Do you foresee going into industrial heat, or district heating in Europe?
We will pursue all of those as business lines in the future. Right now, we are proving ourselves to be uniquely good at delivering power projects. That will be our focus for the near term.
I know you have been focused on the U.S. Where are you looking internationally?
The U.S. is a substantial market at this point in time, so while we do plenty of business development outside of the United States, right now we’re focused on developing at home.
How long will it take for the company and for the industry more broadly to start developing overseas projects in a big way?
We’re close to that already. It’s just a question of what is smart from a business model perspective, and when the timing is right. I’m probably not at liberty to say right now when the timing will be right to really lean into a thriving export side of the business.
If you had to estimate, what would you say is the share of your investors now who are classic energy investors — the types of people who would have been buying into or did buy into shale — versus the share you think are motivated by climate concerns and the clean energy potential of what geothermal is doing? Obviously I realize there’s plenty of overlap. But if you had to discern between those camps, where would you say you’re more indexed?
I would say the majority of energy sector specialists who are investing in this deal are either technology agnostic or are focused on the clean energy side of the business. We do have some marquee shale investors that we will be bringing on as part of the public offering that we’re really, really excited about. So, it’s probably a healthy mix.
Is the shale industry the best analog for how you expect geothermal to scale?
Certainly on the subsurface side it is the closest analog to what we’re doing. We are taking technology that was developed for the shale industry in the subsurface, then we’re deploying it in a similar fashion, which is just over and over and over repeated wells to ensure that we are learning at a really rapid rate and then achieving cost reduction on a learning curve in a single basin. That is a big part of our cost reduction story.
The other thing that we talk a lot about internally is bringing a manufacturing mindset to geothermal energy. It is an industry that has historically been much more akin to a construction industry, building bespoke projects that are tailored for a bespoke commercial need. That is not what we’re trying to do. We’re trying to build a much more scalable business. In order to build a scalable business, you have to establish what is the unit that you are standardizing around and iterating upon. We intend to standardize our design, and iterate and optimize off of a standardized design to allow us to move really fast and to get a lot better, to pull costs out of the business and to be able to scale.
Given how much faster you guys are coming to market, obviously, you have an advantage here over some of the new nuclear technologies being promoted right now. Do you think geothermal is mostly going to eat into the potential market that those could serve? Or do you see nuclear as having different use cases than what geothermal can do?
It’s an overlapping use case, for sure. We don’t talk a lot about eating market share, because the pie is really, really large right now.
How soon before we can anticipate building enhanced geothermal systems on the East Coast and in the Northeast, places where the subsurface heat is not as easily accessible as in the Southwest?
We like to remind people that the demand in the West is massive right now. Probably 18 months ago, we weren’t having as productive conversations with hyperscalers about siting the West as we are today. Today we are having tons and tons of conversations about siting and co-locating alongside geothermal projects in the Western U.S. So the market is really big. We like to mention that just to remind people that expansion is not the only marker of success here.
That said, there is hot rock everywhere, it’s just a question of how deep that hot rock is. We, through our standardized and iterative and repetitive approach in the subsurface, are meaningfully driving cost out of the subsurface, making depth much more of an economic question. If it is more expensive to drill to a certain depth but you already pulled an immense amount of cost per foot out of your drilling, then temperature at depth becomes more accessible even when it’s deeper.
Because drilling is just a portion of the capex of these projects, and a power plant doesn’t care whether it’s located in the West or the East, we basically think that we can move into the Eastern U.S. sooner than we probably had originally thought. It is our goal to do that sometime in the next decade.
In the scant polling I have seen on partisan attitudes on geothermal, most American voters are unaware of it, but among those who are, there seems to be a pretty close match to nuclear in terms of emerging as a rare purple form of energy with closely aligned support between Democrats and Republicans. As you grow, how are you thinking about maintaining that broad appeal and reaching more of those Americans still in the dark?
We benefit from being in an incredibly bipartisan seat right now, and that has been so helpful for our growth and development and is very important to us to maintain going forward. There’s no reason why it shouldn’t be bipartisan. It is a story that is relatable to all. We are highly adjacent to the oil and gas supply chain and oil and gas workforce. We are reliable energy. We are driving towards affordability. We are a clean energy industry with no operating emissions. And really, more than anything, we’re trying to build in a sustainable fashion. We’re trying to deliver projects the right way. It’s something that we have really been able to gain support on both sides of the aisle.
Obviously, that’s been hugely beneficial as we think about extending tax credits. Geothermal energy benefited from increasing tax credits under the Inflation Reduction Act, under President Biden. Then President Trump preserved geothermal energies tax credits in the One Big Beautiful Bill Act. That was hugely helpful to Fervo’s early development.
As we look to bring the cost of the technology down, we hope to continue educating a large group of stakeholders about this technology going forward, and continuing to bring people along with the story, no matter which side of the aisle they sit on.
The Secretary of the Interior said he “absolutely” planned to appeal a ruling that lifted blocks on wind and solar approvals.
The Trump administration is not backing down from its discriminatory policies for approving wind and solar projects. Interior Secretary Doug Burgum testified to Congress on Wednesday that his agency would appeal a recent district court ruling blocking it from enforcing these policies.
“We reject the whole premise,” Burgum said during a House Natural Resources Committee hearing.
Since Trump took office, the Interior Department has issued a series of memos and secretarial orders that systematically disadvantage wind and solar projects. Last July, it issued a memo requiring that nearly all approvals in the wind and solar permitting process be subject to additional reviews by the secretary’s office. A subsequent order required the agency to prioritize permitting projects with greater energy density, meaning ones that produce more power per acre of land, and deemed wind and solar “highly inefficient” compared with coal, nuclear, and natural gas projects.
The policies amounted to an effective freeze on wind and solar development on public lands, while also stalling projects on private lands that require federal consultations, affecting hundreds of clean energy projects. By the end of last year, Democrats saw no point in negotiating on permitting reform if the executive branch could simply make up its own permitting rules. They insisted on limits to executive power before they’d agree to a deal.
Around the same time, a coalition of clean energy groups, including the Clean Grid Alliance, Alliance for Clean Energy New York, and the Southern Renewable Energy Association, challenged the agency’s actions in the U.S. District court for the District of Massachusetts. The Interior’s permitting policies “place wind and solar technologies into second-class status without providing any rational justification for such disparate treatment or drastic policy shifts — unlawfully picking winners and losers among energy sources, contrary to Congress’ intent,” the lawsuit claimed. The groups argued the policies were arbitrary and capricious, in violation of the Administrative Procedures Act. In April, Judge Denise Casper sided with the plaintiffs, putting a temporary injunction on the agency’s wind and solar-hobbling memos.
During Wednesday’s hearing, Representative Susie Lee of Nevada told Burgum that his policies have “created a total permitting mess” in her sunny home state, and asked him what the immediate impact of the court’s order was within his agency. When Burgum responded by denigrating the judge’s decision, Lee asked if he was planning to appeal the order.
“Yeah, absolutely,” he said, asserting that “the idea that a single judge could decide” how the agency conducts permitting “is absurd.”
At the end of her questioning, Lee reaffirmed that the July 15 memo was the single thing stalling a permitting reform deal in Congress. “If you would just rescind that memo, we could get permitting reform passed this Congress, and we can start to talk about permitting all forms of energy.”
Later in the hearing, Burgum also defended another of the administration’s controversial actions regarding renewables. California Representative Dave Min questioned Burgum on his deal to pay the French energy company Total nearly $1 billion to walk away from its offshore wind leases. Was that an appropriate use of money, Min asked, considering so many Americans were struggling with high energy bills? Burgum rejected the premise, asserting several times that the agency merely “refunded” Total’s money.
Current conditions: The heat wave driving temperatures into the triple digits in the Southwest is moving northward to the Mountain West • Temperatures in Timbuktu are forecast to hit 115 degrees Fahrenheit as Mali devolves into a civil war between the government and Islamist militants • Malé, the Maldives’ densely packed island capital often called the Manhattan of the Indian Ocean, is facing days of intense thunderstorms.
Ever since South Korea built the United Arab Emirates’ first nuclear plant as close to on time and on budget as any democratic country has come in recent years, the East Asian nation has been considered one of the only real rivals to China and Russia on construction of new fission reactors. That’s in no small part because many American engineers whose projects dried up in the late 20th century took their skills there, building out more than two dozen commercial reactors and helping to vault Seoul to the vanguard of technological civilizations. Recently, Washington has wanted to re-shore that nuclear knowhow and learn the new project management tricks perfected by South Korea’s state-owned nuclear firm. But Korea Hydro & Nuclear Power’s flagship reactor mirrors the technology covered under the U.S. nuclear giant Westinghouse’s intellectual property. The yearslong standoff between the two companies came to a head last year with a global settlement that, in a controversial move, barred the Koreans from competing against Westinghouse on projects in Europe or North America. Still, the Trump administration has been trying to court Korean investment in the U.S. nuclear sector.
Now it’s coming closer. On Tuesday, KHNP inked a memorandum of understanding with the nuclear division of U.S. utility giant Southern Company to work together on engineering atomic power stations. It’s not a financing deal. Signed at KHNP’s headquarters in Gyeongju, the companies said the partnership would involve technology exchanges, workshops, and sharing best practices. “This agreement is expected to serve as an opportunity for KHNP engineers to expand their horizons globally and provide a growth chance for the domestic engineering system to take a leap forward,” Kim Young-seung, the head of KHNP’s engineering division, World Nuclear News. “We will continue to do our utmost to complete the Korean-style engineering system through close cooperation with overseas operators and international organisations.”
The Environmental Protection Agency has come up with a new way to speed up construction of data centers, power plants, and other industrial facilities: Let them start building before they obtain required federal air permits. The proposal would “bring flexibility to building non-emitting components or structures,” including cement pads and wiring, piping, and support structures. “Today’s proposal works to provide solutions to issues that have held up critical American infrastructure and advance the next great technological forefront,” EPA Administrator Lee Zeldin said in a statement. “Through commonsense permitting reform, the Trump EPA is fixing the broken system of government interference, while continuing to uphold our core mission to protect human health and the environment.”
Surging demand and shortages of raw materials are pushing lead times for high-capacity electrical transformers to as long as four years, PricewaterhouseCooper analysts said at a Reuters event this week. Demand for step-up transformers, which increase the voltage of electricity as it travels across power lines, increased by 274% between 2019 and 2025, while demand for substation transformers soared by 116%. Prices for essential components, meanwhile, have jumped by roughly 80% in five years. As a result, according to PV magazine, some firms are now paying premiums for production slots on projects that aren’t even finalized yet, while others buy refurbished as a stopgap until newer units arrive.
Transformers aren’t the only grid equipment attracting investment. Just this morning, TS Conductor, a manufacturer of advanced conductors that can bolster the capacity of existing power lines, announced the grand opening of its newest factory in South Carolina. The $134 million facility is now “poised to strengthen U.S. domestic supply chains as utilities work toward building a stronger, higher-capacity, more-efficient power grid — all with the speed that American industry needs and the affordability that American ratepayers deserve,” the company said.
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The Trump administration has removed the acting head of the Federal Emergency Management Agency, replacing the political appointee with a 30-year agency veteran who held senior positions in several previous administrations. On Tuesday, E&E News reported that the exit of Karen Evans, a political appointee put in charge of the embattled agency in December, would be the third such departure since President Donald Trump returned to the White House. Her temporary replacement as acting administrator is Robert Fenton, who began work as a regional administrator in 1996 and held the acting chief job twice under the first Trump and Biden administrations — for six months in 2017 and four months in 2021. “I know this year has been challenging for many across the agency,” Fenton wrote in a staff memo Tuesday, a copy of which the newswire obtained.
FEMA has struggled under Trump. As I told you last summer, the agency cracked down aggressively on internal dissent from staffers. Meanwhile, the funding shutdown at the Department of Homeland Security, where FEMA is housed alongside Immigration and Customs Enforcement, “starved” local disaster responses, Heatmap’s Jeva Lange reported in February..
Alsym Energy, as Heatmap’s Katie Brigham reported last year, “thinks it can break the U.S. battery manufacturing curse.” And not just by besting the incumbents already producing the market’s lithium-ion packs, but actually commercializing a whole new type of battery chemistry that instead relies on cheaper and far more abundant sodium as the main energy carrier. On Tuesday, the Massachusetts-headquartered startup inked a deal with the renewable developer Juniper Energy to deploy 500 megawatt-hours of Alsym’s battery systems in California. The deal, the companies said in a press release, “marks a significant shift away from fire-prone lithium-ion dependencies, prioritizing safety, domestic production, and operational efficiency in some of the United States’ most demanding climates.”

If you thought building batteries or transformers was tricky, how about an electricity distribution network in space? That’s what Star Catcher Industries is promising to do. The Jacksonville, Florida-based startup said Tuesday it had raised $65 million in an oversubscribed Series A round. The investment — led by venture capital firms B Capital, Shield Capital, and Cerberus Ventures — brings Star Catcher’s total capital raised so far to $88 million. Founded less than two years ago, the company is developing space-based infrastructure that can deliver electricity on demand to satellites and spacecraft using optical power beaming, a wireless technology involving high-intensity laser light. “This investment underscores the conviction that orbital infrastructure is now as fundamental as terrestrial infrastructure,” Andrew Rush, co-founder and chief executive of Star Catcher, said in a statement. “Every major application driving the space economy — connectivity, computing, security, sensing — is power-limited today. Star Catcher is lifting that ceiling — making it possible to build in orbit at the scale the next century of life on Earth will demand.”
Editor’s note: This story has been updated to correct the location of Terrapower’s isotope plant.