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Inside Climeworks’ big experiment to wrest carbon from the air

In the spring of 2021, the world’s leading authority on energy published a “roadmap” for preventing the most catastrophic climate change scenarios. One of its conclusions was particularly daunting. Getting energy-related emissions down to net zero by 2050, the International Energy Agency said, would require “huge leaps in innovation.”
Existing technologies would be mostly sufficient to carry us down the carbon curve over the next decade. But after that, nearly half of the remaining work would have to come from solutions that, for all intents and purposes, did not exist yet. Some would only require retooling existing industries, like developing electric long-haul trucks and carbon-free steel. But others would have to be built from almost nothing and brought to market in record time.
What will it take to rapidly develop new solutions, especially those that involve costly physical infrastructure and which have essentially no commercial value today?
That’s the challenge facing Climeworks, the Swiss company developing machines to wrest carbon dioxide molecules directly from the air. In September 2021, a few months after the IEA’s landmark report came out, Climeworks switched on its first commercial-scale “direct air capture” facility, a feat of engineering it dubbed “Orca,” in Iceland.
The technology behind Orca is one of the top candidates to clean up the carbon already blanketing the Earth. It could also be used to balance out any stubborn, residual sources of greenhouse gases in the future, such as from agriculture or air travel, providing the “net” in net-zero. If we manage to scale up technologies like Orca to the point where we remove more carbon than we release, we could even begin cooling the planet.
As the largest carbon removal plant operating in the world, Orca is either trivial or one of the most important climate projects built in the last decade, depending on how you look at it. It was designed to capture approximately 4,000 metric tons of carbon from the air per year, which, as one climate scientist, David Ho, put it, is the equivalent of rolling back the clock on just 3 seconds of global emissions. But the learnings gleaned from Orca could surpass any quantitative assessment of its impact. How well do these “direct air capture” machines work in the real world? How much does it really cost to run them? And can they get better?
The company — and its funders — are betting they can. Climeworks has made major deals with banks, insurers, and other companies trying to go green to eventually remove carbon from the atmosphere on their behalf. Last year, the company raised $650 million in equity that will “unlock the next phase of its growth,” scaling the technology “up to multi-million-ton capacity … as carbon removal becomes a trillion-dollar market.” And just last month, the U.S. Department of Energy selected Climeworks, along with another carbon removal company, Heirloom, to receive up to $600 million to build a direct air capture “hub” in Louisiana, with the goal of removing one million tons of carbon annually.
Two years after powering up Orca, Climeworks has yet to reveal how effective the technology has proven to be. But in extensive interviews, top executives painted a picture of innovation in progress.
Chief marketing officer Julie Gosalvez told me that Orca is small and climatically insignificant on purpose. The goal is not to make a dent in climate change — yet — but to maximize learning at minimal cost. “You want to learn when you're small, right?” Gosalvez said. “It’s really de-risking the technology. It’s not like Tesla doing EVs when we have been building cars for 70 years and the margin of learning and risk is much smaller. It’s completely new.”
From the ground, Orca looks sort of like a warehouse or a server farm with a massive air conditioning system out back. The plant consists of eight shipping container-sized boxes arranged in a U-shape around a central building, each one equipped with an array of fans. When the plant is running, which is more or less all the time, the fans suck air into the containers where it makes contact with a porous filter known as a “sorbent” which attracts CO2 molecules.

When the filters become totally saturated with CO2, the vents on the containers snap shut, and the containers are heated to more than 212 degrees Fahrenheit. This releases the CO2, which is then delivered through a pipe to a secondary process called “liquefaction,” where it is compressed into a liquid. Finally, the liquid CO2 is piped into basalt rock formations underground, where it slowly mineralizes into stone. The process requires a little bit of electricity and a lot of heat, all of which comes from a carbon-free source — a geothermal power plant nearby.
A day at Orca begins with the morning huddle. The total number on the team is often in flux, but it typically has a staff of about 15 people, Climeworks’ head of operations Benjamin Keusch told me. Ten work in a virtual control room 1,600 miles away in Zurich, taking turns monitoring the plant on a laptop and managing its operations remotely. The remainder work on site, taking orders from the control room, repairing equipment, and helping to run tests.
During the huddle, the team discusses any maintenance that needs to be done. If there’s an issue, the control room will shut down part of the plant while the on-site workers investigate. So far, they’ve dealt with snow piling up around the plant that had to be shoveled, broken and corroded equipment that had to be replaced, and sediment build-up that had to be removed.

The air is more humid and sulfurous at the site in Iceland than in Switzerland, where Climeworks had built an earlier, smaller-scale model, so the team is also learning how to optimize the technology for different weather. Within all this troubleshooting, there’s additional trade-offs to explore and lessons to learn. If a part keeps breaking, does it make more sense to plan to replace it periodically, or to redesign it? How do supply chain constraints play into that calculus?
The company is also performing tests regularly, said Keusch. For example, the team has tested new component designs at Orca that it now plans to incorporate into Climeworks’ next project from the start. (Last year, the company began construction on “Mammoth,” a new plant that will be nine times larger than Orca, on a neighboring site.) At a summit that Climeworks hosted in June, co-founder Jan Wurzbacher said the company believes that over the next decade, it will be able to make its direct air capture system twice as small and cut its energy consumption in half.
“In innovation lingo, the jargon is we haven’t converged on a dominant design,” Gregory Nemet, a professor at the University of Wisconsin who studies technological development, told me. For example, in the wind industry, turbines with three blades, upwind design, and a horizontal axis, are now standard. “There were lots of other experiments before that convergence happened in the late 1980s,” he said. “So that’s kind of where we are with direct air capture. There’s lots of different ways that are being tried right now, even within a company like Climeworks."
Although Climeworks was willing to tell me about the goings-on at Orca over the last two years, the company declined to share how much carbon it has captured or how much energy, on average, the process has used.
Gosalvez told me that the plant’s performance has improved month after month, and that more detailed information was shared with investors. But she was hesitant to make the data public, concerned that it could be misinterpreted, because tests and maintenance at Orca require the plant to shut down regularly.
“Expectations are not in line with the stage of the technology development we are at. People expect this to be turnkey,” she said. “What does success look like? Is it the absolute numbers, or the learnings and ability to scale?”
Danny Cullenward, a climate economist and consultant who has studied the integrity of various carbon removal methods, did not find the company’s reluctance to share data especially concerning. “For these earliest demonstration facilities, you might expect people to hit roadblocks or to have to shut the plant down for a couple of weeks, or do all sorts of things that are going to make it hard to transparently report the efficiency of your process, the number of tons you’re getting at different times,” he told me.
But he acknowledged that there was an inherent tension to the stance, because ultimately, Climeworks’ business model — and the technology’s effectiveness as a climate solution — depend entirely on the ability to make precise, transparent, carbon accounting claims.
Nemet was also of two minds about it. Carbon removal needs to go from almost nothing today to something like a billion tons of carbon removed per year in just three decades, he said. That’s a pace on the upper end of what’s been observed historically with other technologies, like solar panels. So it’s important to understand whether Climeworks’ tech has any chance of meeting the moment. Especially since the company faces competition from a number of others developing direct air capture technologies, like Heirloom and Occidental Petroleum, that may be able to do it cheaper, or faster.
However, Nemet was also sympathetic to the position the company was in. “It’s relatively incremental how these technologies develop,” he said. “I have heard this criticism that this is not a real technology because we haven’t built it at scale, so we shouldn’t depend on it. Or that one of these plants not doing the removal that it said it would do shows that it doesn’t work and that we therefore shouldn’t plan on having it available. To me, that’s a pretty high bar to cross with a climate mitigation technology that could be really useful.”
More data on Orca is coming. Climeworks recently announced that it will work with the company Puro.Earth to certify every ton of CO2 that it removes from the atmosphere and stores underground, in order to sell carbon credits based on this service. The credits will be listed on a public registry.
But even if Orca eventually runs at full capacity, Climeworks will never be able to sell 4,000 carbon credits per year from the plant. Gosalvez clarified that 4,000 tons is the amount of carbon the plant is designed to suck up annually, but the more important number is the amount of “net” carbon removal it can produce. “That might be the first bit of education you need to get out there,” she said, “because it really invites everyone to look at what are the key drivers to be paid attention to.”
She walked me through a chart that illustrated the various ways in which some of Orca’s potential to remove carbon can be lost. First, there’s the question of availability — how often does the plant have to shut down due to maintenance or power shortages? Climeworks aims to limit those losses to 10%. Next, there’s the recovery stage, where the CO2 is separated from the sorbent, purified, and liquified. Gosalvez said it’s basically impossible to do this without losing some CO2. At best, the company hopes to limit that to 5%.
Finally, the company also takes into account “gray emissions,” or the carbon footprint associated with the business, like the materials, the construction, and the eventual decommissioning of the plant and restoration of the site to its former state. If one of Climeworks’ plants ever uses energy from fossil fuels (which the company has said it does not plan to do) it would incorporate any emissions from that energy. Climeworks aims to limit gray emissions to 15%.
In the end, Orca’s net annual carbon removal capacity — the amount Climeworks can sell to customers — is really closer to 3,000 tons. Gosalvez hopes other carbon removal companies adopt the same approach. “Ultimately what counts is your net impact on the planet and the atmosphere,” she said.
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Despite being a first-of-its-kind demonstration plant — and an active research site — Orca is also a commercial project. In fact, Gosalvez told me that Orca’s entire estimated capacity for carbon removal, over the 12 years that the plant is expected to run, sold out shortly after it began operating. The company is now selling carbon removal services from its yet-to-be-built Mammoth plant.
In January, Climeworks announced that Orca had officially fulfilled orders from Microsoft, Stripe, and Shopify. Those companies have collectively asked Climeworks to remove more than 16,000 tons of carbon, according to the deal-tracking site cdr.fyi, but it’s unclear what portion of that was delivered. The achievement was verified by a third party, but the total amount removed was not made public.
Climeworks has also not disclosed how much it has charged companies per ton of carbon, a metric that will eventually be an important indicator of whether the technology can scale to a climate-relevant level. But it has provided rough estimates of how much it expects each ton of carbon removal to cost as the technology scales — expectations which seem to have shifted after two years of operating Orca.
In 2021, Climeworks co-founder Jan Wurzbacher said the company aimed to get the cost down to $200 to $300 per ton removed by the end of the decade, with steeper declines in subsequent years. But at the summit in June, he presented a new cost curve chart showing that the price was currently more than $1,000, and that by the end of the decade, it would fall to somewhere between $400 to $700. The range was so large because the cost of labor, energy, and storing the CO2 varied widely by location, he said. The company aims to get the price down to $100 to $300 per ton by 2050, when the technology has significantly matured.
Critics of carbon removal technologies often point to the vast sums flowing into direct air capture tech like Orca, which are unlikely to make a meaningful difference in climate change for decades to come. During a time when worsening disasters make action feel increasingly urgent, many are skeptical of the value of investing limited funds and political energy into these future solutions. Carbon removal won’t make much of a difference if the world doesn’t deploy the tools already available to reduce emissions as rapidly as possible — and there’s certainly not enough money or effort going into that yet.
But we’ll never have the option to fully halt climate change, let alone begin reversing it, if we don’t develop solutions like Orca. In September, the International Energy Agency released an update to its seminal net-zero report. The new analysis said that in the last two years, the world had, in fact, made significant progress on innovation. Now, some 65% of emission reductions after 2030 could be accounted for with technologies that had reached market uptake. It even included a line about the launch of Orca, noting that Climeworks’ direct air capture technology had moved from the prototype to the demonstration stage.
But it cautioned that DAC needs “to be scaled up dramatically to play the role envisaged,” in the net zero scenario. Climeworks’ experience with Orca offers a glimpse of how much work is yet to be done.
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The maker of smart panels is tapping into unused grid capacity to help power the AI boom.
The race for artificial intelligence is a race for electricity. Data centers are scrambling to find enough power to run their servers, and when they do, they often face long waits while utilities upgrade the grid to accommodate the added demand.
In the eyes of Arch Rao, the CEO and founder of the smart electrical panel company Span, however, there is a glut of electricity waiting to be exploited. That’s because the electric grid is already oversized, designed to satisfy spikes in demand that occur for just a few hours each year. By shifting when and where different users consume power, it’s possible to squeeze far more juice out of the existing system, faster, and for a lot less money, than it takes to make it bigger.
This is what Span’s smart panel does — it manages the energy drawn by household appliances to help homeowners integrate electric vehicle chargers and heat pumps without triggering the need for electrical upgrades.
Now the age of AI has opened up new opportunities for the company. Last month, Span announced the launch of XFRA, a device that works with Span’s smart panel to power AI applications by tapping into the unused electrical capacity available to homes and businesses.
The company refers to XFRA as a “distributed data center.” It’s sort of like if you chopped up a full-scale data center into washing machine-sized boxes and plugged them into peoples’ homes; Span’s smart panel then acts as a conductor, orchestrating XFRA’s energy consumption to take advantage of unused power capacity without stepping on the home’s other energy needs. In exchange for hosting one of these XFRA “nodes,” Span will offer homeowners and tenants deeply discounted, if not free electricity and internet service.
The idea sounded audacious, verging on fantastical, until I watched the economics play out in real time at one of Span’s labs in a warehouse south of San Francisco. Ryan Harris, the company’s chief revenue officer, showed me an XFRA prototype — a metal box about the size of a freezer chest stuffed with Dell servers and Nvidia liquid-cooled GPUs. Span was renting out the processing power from this node and six others to AI users through an online marketplace. On a computer screen next to the unit, a dashboard showed the revenue flowing in from the fleet — $500 over the past 24 hours, and more than $21,000 in the previous three weeks. The numbers continued to tick up as I stood there.
When I first planned to write about Span, XFRA was still a secret. I reached out because its smart panel business, which debuted in 2019, seemed to suddenly take off.
In February, Span announced that PG&E, the largest utility in California, would be installing its devices in thousands of homes beginning this summer. Then in March, the company revealed a partnership with Eaton, one of the biggest legacy electrical equipment companies in the world. Eaton is investing $75 million in Span and will begin selling co-branded electrical panels to its extensive network of distributors, installers, and homebuilders later this year. With the launch of XFRA, Span is becoming something like a utility itself. To date, the company has raised more than $400 million, and will soon close a nearly $200 million Series C.
Of course it will take more than smart electrical panels to serve data centers’ soaring power needs. In this era of unprecedented energy demand growth, building a bigger electrical system is unavoidable — but the size of the investment, and the cost impacts on everyday electricity customers, are malleable. Several recent studies have shown just how big the opportunity is to get more energy out of our existing infrastructure if the entire system can become a bit more flexible.
Last year, Duke University researchers found that on average, the U.S. is utilizing only about half of our electricity generation capacity. Nationwide, they estimated, the grid could accommodate at least 76 gigawatts of new load — close to the total generation capacity installed in California — without having to upgrade the electrical system or build new power plants, so long as those new end-users were somewhat flexible with when and how much electricity they used.
More recently, in a report commissioned by a coalition called Utilize, of which Span is a member, the Brattle Group found that milking just 10% more from our existing grid infrastructure on an annual basis could reduce electricity rates for all end users by 3.4%. Utilities can sell more energy, faster, and spread the fixed costs of running the system across more customers.
What all this meant in practice did not fully click for me until I saw a demonstration of Span’s panel at the lab a few weeks ago. Harris, the CRO, led me to a free-standing wall lined with household appliances, a stripped-down version of an all-electric home. A minisplit heat pump whirred while a high-speed electric vehicle charger was juicing up a Rivian parked on the warehouse floor. A TV screen displayed the amount of power going to each device, as measured by Span’s electric panel.
Together, the heat pump and charger were using about two-thirds of the electric capacity of this demonstration home, which was running on a 100-amp utility service connection. The charger alone was using 48 amps.
The owner of this theoretical home would typically not have been allowed to install such an energy-intensive EV charger without upgrading to 200-amp service. Electric codes require that residential electrical systems have room for the rare scenario that a home’s major appliances all run at once, for safety reasons. Otherwise, the occupants might accidentally try to draw more power than their utility connection can deliver, overheat their wires, and start a fire. 100-amp connections are exceedingly common in homes designed to use gas or propane for cooking and heating, but once you replace those appliances with electric versions, or add an EV charger, you start to push the limit.
A service upgrade to 200 amps can take many months and cost several thousands of dollars. The utility typically has to run new wiring to the house, and might even have to augment the grid infrastructure serving the neighborhood.
Span’s smart panel offers an alternative.
“Shall we turn on some load?” Harris said. An engineer on Span’s product team turned on the demo home’s electric water heater, and I watched as the chart on the screen adjusted. The water heater jumped from zero to 22 amps, while the EV charger’s amperage decreased from 48 to 33. When the engineer switched on the clothes dryer, drawing 24 amps, the EV charger’s amperage dropped further.
The electrical panel was tracking how much power was flowing to each of its circuits and throttling the EV charger in response. When the team dialed up the electric stove to heat a pot of water, the EV charger shut off altogether.
Next, Harris requested a boost to the “garage” sub-panel, simulating a hot tub or some power tools kicking on. Soon, the water heater shut off, too. “You have 50 gallons of hot water, so it’s not going to have any negative impact on the customer in that moment,” Harris told me. He showed me an alert that appeared on the Span phone app notifying the homeowner that the system was temporarily limiting power to the EV charger and water heater in order to power other devices.
Users can choose which appliances the system bumps first. While some devices, such as EV chargers, water heaters, and heat pumps, have the ability to be ramped up and down, others will simply shut off.
At $2,550 excluding labor for the smallest, most basic smart panel, and just over $4,000 for the biggest one, Span is more expensive than the average dumb panel, which can come in under $1,000. Depending on the home and the complexity of a service upgrade, however, it’s often cheaper to install Span than to move to 200 amps. It’s also almost certainly faster.
Span’s first generation product couldn’t do any of this. Initially, the company’s value proposition was just to give people more control over their energy usage. The original Span panel gave homeowners with batteries the ability to select which devices they wanted to power during an outage and ensure they didn’t accidentally lose charge on non-essentials. The company had to build an initial customer base and validate the technology in the real world, Rao told me, before it could earn the credibility (and the capital) to deploy the fully realized version of the product.
In 2023, Span debuted “PowerUp,” the software that makes what I witnessed at the lab possible. With PowerUp, Span’s smart panel went from being a cool gadget to a money-saver, helping homeowners skip utility service upgrades. The success of PowerUp opened the door for Span to engage with larger partners, starting with homebuilders.
“We had to demonstrate that we were safe and scalable in the home retrofit category to then get homebuilders — who are typically very, very cost sensitive, are not often at the tip of the spear in terms of technology adoption — to say, this is a proven technology, and it saves you money,” said Rao.
Residential developers face similar problems as homeowners, but on a bigger scale. While 200-amp connections have become more standard over the past few decades, new electrical codes that require either fully electric or electric-ready construction are pushing the limits.
“Now the load calculations will put them at 300 or 400 amps of service per home,” Rao told me. “Multiply that by a community of 500 homes, and suddenly you’ve doubled the amount of interconnection you need to bring from the utility.”
This raises the cost of development, and it can also increase the wait time — potentially by years — to get hooked up to the grid. Again, Span offers an alternative. To date, nearly half of the top 20 homebuilders across the U.S. have used the company’s technology, Rao told me. More broadly, its electrical panels have been installed in tens of thousands of homes in all 50 states.
I should note that Span is not the only solution on the market for homeowners or homebuilders to avoid service upgrades — the main alternative is just choosing appliances that don’t use so much power. There are water heaters, clothes dryers, and EV chargers on the market that run on lower amperage, and startups like Copper and Impulse Labs are making stoves with integrated batteries that enable them to do the same. There are also Span-adjacent technologies such as smart circuit splitters that let you plug two power-hungry devices, like an EV charger and a clothes dryer, into the same circuit, and the device will safely modulate power between the two.
“You can hack your way around both problems — one, of a panel upgrade, and two, a Span upgrade, which is also expensive — with cheaper solutions,” Brian Stewart, the co-founder of Electrify Now, a group that provides education and advocacy on home electrification, told me. “But it’s less elegant, let’s just say, than the Span solution.”
Though he started at the home level, Rao has always had his sights set on a much bigger customer — utilities. Several Span executives I spoke to referenced an “infamous” Powerpoint slide from the early days of the company with a bar chart that showed how the company would scale in three phases. First came “back-up,” referring to Span’s initial home battery management product. Next was “power-up,” the software that enabled electrification by avoiding service upgrades. The third was “fleet.”
The same safety principles that trigger service upgrades at individual homes also apply upstream at the neighborhood level. For example, the size of a neighborhood’s transformer, the equipment that changes the voltage of the electricity as it moves along the grid, depends on the combined amperage of the homes it serves. If all those homes are installing EV chargers or heat pumps or whatever else and starting to use more electricity, the utility will have to upgrade the transformer — a cost that gets spread across all of its customers. If a critical mass of the homes have Span panels, however, they can avoid this.
Partnering with major homebuilders earned Span “the right to sit at the table with utilities,” Rao told me, “and say, look, we’ve done this at the home level, at the community level. Imagine if you could do this at the grid level, where the benefit doesn’t just accrue to individual customers or home builders, it can accrue to all rate payers?”
I got a taste of what this looks like back at the lab, where Harris showed me Span’s “fleet capability.” There were actually three demonstration homes set up on the warehouse floor, and Harris showed me how a utility could coordinate a response across multiple Span panels to keep a neighborhood within its safe energy limits.
Imagine it’s a really hot day, and the utility is on the verge of having to institute rolling blackouts. Instead, it can implement what’s called a dynamic service rating event, sending a signal out to the Span panels served by a given transformer to reduce their electrical limit from 100 amps to 60, for example. Rather than the entire neighborhood losing power, a few homes would see their EV charging cut back or their thermostats go up by a few degrees. Of course, not everybody will want to give this kind of control to the utility; customers often cite concerns about comfort and convenience as reasons they are skeptical of these kinds of programs. When I asked Harris whether participating would require that Span customers opt in, he said it was more likely to be opt-out.
Span has done several pilot projects testing this capability. Installing electrical panels is too complex for utilities to do en masse, though. So the company developed Span Edge, a smaller version of its panel that can be installed at a building’s electricity meter. It does all the same things the larger electrical panel does, without needing to serve as the home’s central nervous system. It still enables homeowners to avoid service upgrades by throttling EV chargers or whatever other devices are hooked up to it, but it’s much simpler to install.
This is the device that the California utility PG&E will begin deploying in homes later this summer. The company will offer Span Edge to homeowners who are installing appliances that might trigger an electrical upgrade, or are considering doing so in the future, through a program called PanelBoost. It’s entirely voluntary, and while participants will have to pay for installation, the panel itself comes gratis.
“This is the first time that there’s a large-scale direct purchase of Span equipment by a utility,” Alex Pratt, Span’s vice president of business development, told me. “This has long been the North Star for the company.”
Paul Doherty, the manager for clean energy and innovation communications at PG&E, told me the company saw Span Edge as a “win, win, win for PG&E, for our customers, and for the environment.” It enables customers to electrify their homes more quickly and affordably, and for PG&E to sell more electrons without raising rates.
“We’re very bullish about the opportunity for this technology and the benefit that it will bring for the grid and for our customers here in California,” Doherty told me.
Rao sees XFRA as a natural evolution of Span’s basic premise. The company has found that 98% of its customers that have 200-amp service connections have about 80 amps available at any given time, Harris told me. Hosting an XFRA node enables homeowners to monetize that unused capacity.
To start, Span is prioritizing getting XFRA into newly built homes, where the developer handles customer acquisition and installing at scale is straightforward since every home is roughly the same. The company has partnered with the developer PulteGroup to roll out a 100-home pilot program for a total of over 1.2 megawatts of compute capacity. The partners have not specified where it will be yet or whether there will be a single offtaker for the compute.
In the longer term, Rao told me, XFRA could be the “unlock” that makes electrification more affordable for people. “There is a utopian end state in my mind where XFRA allows more of our customers to get free energy, free backup, and free internet,” he said.
First, the company will have to find out if anyone is actually willing to let XFRA into their home. During my final conversation with the CEO, after my lab visit, he showed me the infamous slide forecasting the company’s growth from “back-up to power-up to fleet.” The y-axis on the chart showed the number of homes per year the company could address at each stage. The bar for back-up systems landed at 5,000 per year, Power-up came to nearly 100,000. Suffice it to say, Span hasn’t hit these numbers.
“Are you where you want to be today?” I asked him.
Of course, he wasn’t going to say no. “We have contracts in place for hundreds of thousands of homes already with utilities,” he said. “Right now our focus is on execution — delivering on that scale, as opposed to finding that scale. It’s a deployed product, it’s not a downloadable app, so it takes time to physically deploy hundreds of thousands of endpoints. So I think that scale is coming.”
After years of dithering, the world’s biggest automaker is finally in the game.
The hottest contest in the electric car industry right now may be the race for third place.
Thanks to Tesla’s longtime supremacy (at least in this country), its two mainstays — the Model Y and Model 3 — sit comfortably atop the monthly list of best-selling EVs. Movement in the No. 3 spot, then, has become a signal for success from the automakers attempting to go electric. The original Chevy Bolt once occupied this position thanks to its band of diehard fans. Last year, the brand’s affordable Equinox EV grabbed third. And then, earlier this year, an unexpected car took over that spot on the leaderboard: the Toyota bZ.
The surprise is not so much the car itself, but rather its maker. Over the years, we’ve called out Toyota numerous times for dragging its feet about electric cars. The world’s largest automaker took the hybrid mainstream and still produces the hydrogen-powered Mirai. Nevertheless, Toyota publicly cast doubt about the viability of fully electric cars on several occasions and let other legacy car companies take the lead. Its first true EV, the bZ4X, was a disappointment, with driving range and power figures that lagged behind the rest of the industry.
Suddenly, though, the Toyota narrative looks different. Working at its trademark deliberate pace, the auto giant is revealing a batch of new EVs this year, just as competitors Ford, GM, Honda, and Hyundai-Kia are pulling back on their electric lines (and writing off billions of dollars to tilt their companies back toward fossil fuels). There is the Toyota bZ, which Car and Driver called “quicker, nicer inside, and better at being an EV” than the bZ4X, its predecessor. There is the C-HR, a small crossover that had been gas-powered before it became fully electric this year. And there is the large Highlander SUV, a popular nameplate that’s about to become EV-only.
To see what’s changed with the cars themselves, I test-drove the C-HR last week. A decade ago, I’d taken its gas-powered predecessor on a road trip down Long Island and found it to be a fun but frustrating vehicle. Toyota went way over the top with the exterior styling back then to make the little car scream “youthful,” but under the hood was a woefully underpowered engine that took about 11 seconds to push the C-HR from 0 to 60 miles per hour. Now, thanks to the instant torque of electric motors, the new version finally has the zip to go with its looks: It’ll get to 60 in under five seconds, and feels plenty zoomy just driving around town.
Inside, C-HR feels like an evolved Toyota that isn’t trying too hard to be a Tesla. The brand took the two-touchscreen approach, with a large one in the center console to handle main functions such as navigation, entertainment, and climate control, and a smaller one in front of the driver’s eyes where the traditional dashboard would be. There are still physical buttons on the wheel to manipulate music volume and cruise control, but climate controls are entirely digital.
The big touchscreen is a work in progress. It’s too crowded with information compared to a clean overlay like Tesla’s or Rivian’s, and the design of the navigation software had some profound flaws. (Whether you’re using the voice assistant or keyboard input to search for a destination, the system lags a troubling amount for a brand-new car. Maybe Toyota just expects you to use Apple CarPlay and ignore its built-in system.) Still, the interface is more iPhone-like and intuitive than what Hyundai and Kia are using in their EVs.
Here’s the real problem with the C-HR: Although it accomplishes the mission of feeling like a fun-to-drive Toyota that happens to be electric, it’s not terribly good at being an electric car. The Toyota lacks one-pedal driving, the delightful feature where the car slows itself as soon as you let off the accelerator, negating the need to move your foot between two pedals all time. Nor does it have a front trunk, a.k.a. frunk, the fun bonus on EVs made possible by the absence of an engine. According to Toyota, the C-HR is so small that engineers simply didn’t have room for a frunk (or a glovebox, for that matter).
The C-HR’s NACS charging port makes it possible to use Tesla Superchargers, and its charging port location on the passenger’s side front should make it simple to reach them. But instead of sitting on the corner of the car, easily reachable by a plug right in front of the parked vehicle, the port is several feet back, just behind the front wheel. And its door opens toward the charger, so the cord has to reach over or under the door that’s in the way. I made it work at a Supercharger in greater San Diego, but only after several frustrating tries and with less than an inch of cord to spare.
Those are the complaints of a longtime EV driver, and they might not matter to some C-HR buyers. The deepest oversight is the C-HR’s nav, which, at least right now, doesn’t have compatible charging stations built into its route planning — a warning message will notify you if the chosen route requires recharging to reach the final destination, but the car won’t tell you where to go. This is a glaring omission for potential buyers who’ll be taking their first EV road trip. (Get PlugShare, folks.) Planned charging is effectively an industry standard — even Toyota’s legacy competitors like Chevy and Hyundai will choose appropriate fast-chargers and route you to them, even if their interface isn’t as seamless and satisfying as what’s in a Tesla or Rivian. At least that’s a problem that could be solved later via software update, though.
Because of these faults, it’s difficult to imagine someone choosing this as their second or third EV. But maybe that’s not the game at all. There is a legion of Toyota drivers out there, many of whom might think about buying their first electric car if their brand built one. Despite its flaws, the C-HR is that. It’s got enough range for city living and occasional road trips, enough power to be fun to drive, and a Toyota badge on the hood.
Whatever their quirks, the very existence of the C-HR and its electric stablemates is a testament to Toyota’s plan to play the long game with EVs rather than ebb and flow with every whipsaw turn in the American car market. And they’re here just in time. Amidst volatile oil prices because of the Iran war, drivers worldwide are more interested in going electric.
In the U.S., that interest has buoyed used EV sales — not new — because so few affordable options are on the market. Although C-HR starts near $38,000, Toyota has begun to offer discounts that would bring it in line with gas-powered crossovers that are $5,000 cheaper. Maybe that’ll be enough for the subcompact to join its bigger sibling, the bZ, on that list of best-sellers.
Current conditions: A raging brushfire in the suburbs north of Los Angeles has forced more than 23,000 Californians to evacuate • The Guayanese capital of Georgetown, newly awash in offshore oil money, is also set to be drenched by thunderstorms through next week • Temperatures in Washington, D.C., are nearing triple digits today.
A bipartisan budget deal to fund roads, railways, and bridges for the next five years would also slap a $130 per year fee on drivers registering electric vehicles, with a $35 fee for plug-in hybrids. Late Sunday, lawmakers on the House Transportation and Infrastructure Committee released the text of the 1,000-page bill. Roughly a sixth of the way through the legislation is a measure directing the Federal Highway Administration to impose the annual fees on battery-electric and plug-in hybrid vehicles — and to withhold federal funding from any state that fails to comply with the rule. If passed, the fees would take effect at the end of September 2027. The fees — which increase to $150 and $50, respectively, after a decade — are designed to reinforce the Highway Trust Fund, which has traditionally been financed through gasoline taxes. In a statement, Representative Sam Graves, a Missouri Republican and the committee’s chairman, said the legislation “ensures that electric vehicle owners begin paying their fair share for the use of our roads.” But Albert Gore, the executive director of the Zero Emission Transportation Association, called the proposal “simply a punitive tax that would disproportionately impact adopters of electric vehicles, with no meaningful impact on” maintaining the fund. “Drivers of gas-powered vehicles pay approximately $73 to $89 in federal gas tax each year,” Gore said. “The proposed fee would charge an unfair premium on EV drivers, at a time when all Americans are looking for ways to save money.”
The Department of Justice, meanwhile, is preparing to weigh in on whether Elon Musk’s artificial intelligence company, xAI, is operating an illegal gas electrical plant to power its data center in Southaven, Mississippi. Last month, the NAACP and the Southern Environmental Law Center accused xAI of operating 27 gas turbines without pollution controls or Clean Air permits at the server farm, known as Colossus 2. Last week, the groups asked the federal court for a preliminary injunction to stop pollution from what E&E News described as “tractor-trailer-sized generators.” In response, the Justice Department cited President Donald Trump’s support for AI and said it was “evaluating possible intervention or amicus participation in this lawsuit.” It’s not the only agency riding in to aid Musk and his ilk. As I told you last week, the Environmental Protection Agency just proposed a new rule that would allow data centers and power plants to begin construction without air permits.
The Environmental Protection Agency has proposed two separate rules to delay and rescind drinking water limits on four “forever chemicals,” the class of cancer-causing compounds that spread in water and accumulate in the human body. The rules, as The Guardian noted, “must go through an approval process that can take several years, and almost certainly will be challenged in court.” Over the past decade, perfluoroalkyl and polyfluoroalkyl substances, known as PFAS, were discovered to be pervasive in the drinking water of some 176 million Americans. The chemicals — which are linked to kidney cancer, immune system suppression, and developmental delays in infants — are estimated to be in nearly 99% of Americans’ blood. In 2024, the Biden administration established limits on six substances, as Heatmap’s Jeva Lange reported at the time. But the Trump administration will now ax protections for four of the substances and provide companies with an extra two years to comply with rules on the other two. The move, The New York Times reported, has already “sparked fury within the Make America Healthy Again movement, a diverse group of anti-vaccine activists, wellness influencers and others who make up a key part” of Trump’s base.

India was once a forbidden prize for nuclear exporters. The world’s most populous nation, its metropoles choked by coal smog, operates two dozen commercial nuclear reactors — and wants more. But until earlier this year, the country was hamstrung by the haunting memory of Union Carbide’s 1984 accident at its Bhopal plant, where a leak killed thousands of Indians and the American chemical giant avoided any serious liability. To prevent a similar dynamic in the nuclear sector, New Delhi passed a law in 2010 that put developers on the hook for any accidents. The statute effectively banned American, European, or East Asian companies from attempting to build any reactors, lest they risk bankruptcy; only Russia’s state-owned nuclear company was willing to sell its wares on the subcontinent. In December, as I told you at the time, the Indian parliament passed legislation to reform the liability law and welcome more foreign developers into its market. Already, as I reported in a scoop for Heatmap last month, a Chicago-based fuel startup is making moves to sell its product in India.
Fast forward to this week: On Monday, a high-level delegation of U.S. industry officials flew to New Delhi to meet with Indian science minister Jitendra Singh and discuss “private investment opportunities” to export small modular reactors and other American nuclear technology, NucNet reported.
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Ford Energy, the wholly owned battery storage business forged out of Ford Motor’s electric vehicle efforts, has landed its first big deal. On Monday, the company announced a five-year framework agreement with French utility giant EDF’s North American renewables division to design battery storage systems for the multinational. As part of the deal, EDF will buy up to 4 gigawatt-hours of battery blocks per year, totaling up to 20 gigawatt-hours by the end of the contract. The first deliveries are expected in 2028. Lisa Drake, Ford Energy’s president, said the deal “validates the market’s need for” a battery storage supplier “that combines industrial-scale manufacturing discipline with full lifecycle accountability.” In a statement, EDF said Ford’s “commitment to domestic manufacturing and its rigorous approach to traceability and lifecycle support align with the standards we hold across our portfolio.”
Last August, I told you that Anglo American’s deal to sell the U.S. giant Peabody Energy its Australian coal business for $3.8 billion collapsed. Well, nine months later, the London-based mining behemoth has found a new buyer for the same price. On Monday, the Financial Times reported that Anglo American would sell the Australian coal mining operations to Dhilmar, a little-known and privately held company that was formed out of some Canadian mining assets and incorporated in London in 2024. The value of the deal? $3.88 billion. The agreement, which faces years of arbitration, closes what the newspaper called “a difficult chapter for Anglo” after last year’s sale to Peabody fell apart following an explosion at one of the mines included in the deal.
India isn’t the only country getting its act together on new nuclear plants. On Monday, Sweden’s next-generation reactor champion, the startup Blykalla, submitted the first-ever application to regulators in Stockholm to build the nation’s first commercial advanced nuclear reactor park two hours north of the capital. The 330-megawatt facility would include six lead-cooled units Blykalla called “advanced modular reactors,” or AMRs. “This application is a historic first for Sweden,” Blykalla CEO Jacob Stedman said in a statement. “We’re not just planning an advanced reactor park — we’re building Sweden’s energy future and putting the country at the forefront of the global nuclear power renaissance.”