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Stellantis is pulling back at Belvidere.

One of the biggest wins the United Auto Workers’ secured in its historic negotiations with the Big Three automakers last year was a commitment from Stellantis to reopen and expand its shuttered factory in Belvidere, Illinois. Now the company is shelving those plans, which included retooling the factory to produce electric vehicles and EV batteries, and suing the union for threatening to strike in response.
The dispute illustrates a new turn in the EV transition. Whereas last year auto workers were wary of the transition and fighting to keep their jobs intact, now their jobs are dependent on that transition actually happening, and happening soon. The UAW is concerned that the company will delay the plant’s reopening until 2028 — after the union’s contract expires.
Stellantis idled the Belvidere plant, which previously produced Jeep Cherokees, in February 2023, laying off more than 1,300 workers. But under its agreement with the UAW, the company said it would spend nearly $5 billion to restart the factory. The contract includes commitments to opening a parts distribution hub there this year, producing a new mid-size truck there by 2027, and building an electric vehicle battery plant at the site by 2028. Not only would jobs at Belvidere be restored, but the battery plant was expected to employ an additional 1,300 people. Former Belvidere employees would also be reclassified as temporary layoffs and receive partial pay and full healthcare benefits until operations started up again.
President Joe Biden celebrated Belvidere as a “great comeback story” in his State of the Union speech in March. “Instead of an auto factory shutting down, an auto factory is reopening and a new state-of-the-art battery factory is being built to power those cars,” he said. “Instead of a town being left behind it’s a community moving forward again!”
In July, plans to turn Belvidere into an EV hub seemed to be taking shape when the Department of Energy selected Stellantis for a $335 million grant to transition the plant’s assembly lines to be able to produce electric vehicles. The grant website says the project was anticipated to incorporate “significant upgrades” to the plant’s infrastructure and re-employ about “1,450 unionized and highly skilled employees.” Stellantis, however, did not issue any press releases about the grant. In a statement to the Chicago Tribune, the company said it was “an important step in continuing to work toward finalizing a sustainable solution” for Belvidere.
About a month later, the narrative around Belvidere started to shift. UAW president Shawn Fain posted a video on social media claiming something was “rotten” at Stellantis and accused the company of “putting the brakes” on its plans to reopen the plant. On August 20, Stellantis confirmed that “plans for Belvidere will be delayed,” though it “firmly stands by its commitment” to reopen the plant. The company’s explanation for the decision was vague and did not include a new timeline. “To ensure the Company’s future competitiveness and sustainability,” it said, “it is critical that the business case for all investments is aligned with market conditions and our ability to accommodate a wide range of consumer demands.”
As it stands, the business is not exactly in a sustainable place. In July, Stellantis reported that its U.S. revenues were down 16% compared to the first half of last year. Declining sales have left dealerships with a glut of inventory. Fain blames the company’s poor performance on its CEO Carlos Tavares, questioning how “market conditions” could be holding back investments in Belvidere when Tavares took a 56% raise last year, “making him the highest paid auto executive outside of Tesla.”
In response, the company published a fact check of the union’s claims, which notes that “there is indisputable volatility in the market, especially as the industry transitions to an electrified future. Over the past year, numerous companies across the industry have announced investment and product delays as well as outright product cancellations.” Stellantis currently sells just one EV in the U.S., the Fiat 500e, which it manufactures in Italy; in September, the company announced it had suspended production due to poor sales, though it still has several new EV models slated to launch later this year.
More than a dozen local UAW units all over the country filed grievances against Stellantis in August, arguing that the company’s “failure to plan for, fund and launch these programs constitute a violation” of its contract. The union has threatened to strike if the grievances are not addressed, citing its “right to strike over product and investment commitments” — another provision of the 2023 contract.
Stellantis denies that it has violated the contract and thrown the accusation back at UAW, noting that the agreement included a clause that says it is understood that the investments are “contingent upon plant performance, changes in market conditions, and consumer demand.” It has since filed eight lawsuits against the union and several of its locals for threatening to strike.
The company has also not completely abandoned its plans for the EV transition. A few weeks ago, it announced it would invest more than $406 million to prepare three Michigan factories for EV production. During a livestream in September, Fain wrote off those investments as representing just a small portion of what the company committed to.
In response to questions about why investment in Belvidere was delayed, whether the company would still pursue the federal grant, or what the new timeline for the plant was, a representative from Stellantis sent me bullet points from the previously published fact check.
The Department of Energy did not answer questions about the status or timeline for the factory conversion grant.
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New tariffs and price floors for imported polysilicon aim to protect U.S. producers from Chinese competition.
Almost exactly a month after President Donald Trump’s landmark tax law effectively eliminated a key incentive for solar developers to buy panels made in America, his administration is throwing a lifeline to manufacturers behind the nation’s fastest-growing and quickest-to-deploy source of electricity.
On Thursday afternoon, after the markets closed, the White House announced new tariffs and minimum import prices for imported polysilicon as part of an effort to prop up the domestic supply chain for the primary ingredient in semiconductors and solar panels.
The levies come in response to complaints from polysilicon makers that the dearth of U.S. factories demanding solar-grade polysilicon made it difficult to compete with Chinese giants who benefit from selling both the solar- and microchip-grade versions of the ultra-pure industrial material derived from quartz and sand. The companies made the petition under Section 232 of the Trade Expansion Act of 1962, which gives the White House the power to restrict imports and charge tariffs on imports that demonstrably impair national security.
The Trump administration will impose a 15% tariff on all imports and set baseline prices at which the levies would apply for each component in the solar supply chain. Polysilicon will have a minimum import price of $20 per kilogram. Wafers, the ultra-thin slice of crystalline silicon that acts as the foundation of a photovoltaic cell, and ingots, the silicon material before it’s sliced, will start at $100 per kilogram. Cells, the tiny silicon-based devices that absorb photons from sunlight and break away electrons that generate electrical currents, will have a minimum price of $0.22 per watt. Modules, the completed panels, are $0.38 a watt.
The majority of U.S. solar factories simply assemble wafers and cells into modules, leaving them reliant on imports. But the policy won’t hit all at once. The Commerce Department is giving companies 120 days before the restrictions kick in.
The agency will also set up an incentive program that allows manufacturers that make large capital investments in the U.S. to avoid the worst of the levies. Jeffrey Kessler, the Under Secretary of Commerce in charge of executing on 232 cases, pushed for the provision as a bid to avoid what happened when Europe attempted to protect its own solar manufacturers by setting a minimum import price meant to keep Chinese companies from flooding the market. That policy ended up subsidizing the very Chinese parent companies putting market domination ahead of profits back home.
Avoiding that outcome is tricky under any circumstances. China and the U.S. don’t have a tax treaty, which makes it difficult for American authorities to confirm a company’s ownership structure. The surest way to seal off the U.S. market is with 100% tariffs such as those imposed on Chinese electric vehicles.
In this case, the Commerce Department decided to allow companies with active plans to onshore the solar supply chain to apply for an exemption from the new trade rules. Ahead of the announcement, sources familiar with the talks listed South Korean giant Qcells, which just opened the nation’s largest integrated solar factory in Georgia, as one obvious example of a company that would pass muster.
Solar manufacturers applauded the move. “Today’s decision from the White House balances the reality of where America’'s solar energy manufacturing is today while advancing our collective ambition to onshore the entire supply chain from polysilicon to finished panels in the U.S.,” Andy Park, the global CEO of Qcells, said in an emailed statement. “American solar manufacturers are ready to rise to the occasion.”
The trade action “creates a market where wafer and cell manufacturing can happen in the United States, and companies can go fully vertically integrated,” Nick Iacovella, the executive vice president of the Coalition for a Prosperous America, a bipartisan trade association that represents manufacturing companies at every stage of the polysilicon supply chain, told Heatmap.
“What this does is cement a key input in the supply chain that’s critical not just for chips, but for the most efficient, best-performing solar modules,” he said. “We shore up our chip supply chain at a time when there is a greater urgency to derisk from China invading Taiwan — and also during a time when the AI data center boom is driving massive demand for new energy generation, with solar driving a lot of the new capacity coming onto the grid.”
The levies come a week after the Federal Communications Commission banned the use of new types of foreign-made inverters, the equipment needed to patch solar panels onto the grid. Analysts said the ban would have a limited effect on the solar industry, since it allows for the current models on the market to be sold. The purpose of that policy is to prop up domestic factories at a moment when Europe, despite its struggle to reindustrialize, is experiencing an inverter manufacturing boom.
Despite those intentions, multiple industry sources who spoke on condition of anonymity told Heatmap that trade restrictions alone would likely prove insufficient to prop up a domestic solar supply chain at the scale needed to minimize imports.
The latest data from the Rhodium Group found that new U.S. investments in solar factories peaked from the second half of 2022 through the first quarter of 2025. During that time, as Emily reported in May, the announced projects averaged more than $2 billion per quarter. At least 30 new utility-scale solar factories opened across the U.S. just last year.
Since then, development has plummeted. Investment in new solar factories announced fell to about $350 million in the first quarter of 2026, a drop of more than 80%.
By raising the price of panels overall, the Commerce Department is providing a particular boon to America’s leading solar manufacturer, First Solar. While the Phoenix-based panel-maker’s thin-film cell technology doesn’t use polysilicon, the price hike from the tariffs will give the company an edge by allowing the company to either raise its prices to match new industry-wide benefits or undercut its competitors. Investors in the company told Heatmap its recent bookings average sales of about $0.36 per watt.
Another clear winner is T1 Energy, which Roth analysts say “would eventually be a beneficiary once it ramps up its U.S. cell manufacturing, which is now expected to come online” next year. The company’s share price spiked more than 10% in after-hours trading, while First Solar was up more than 8%.
“There are a lot of people in the administration who support solar,” Iacovella said. “They just don’t want a bunch of Chinese solar panels.”
Still, he added, “this is all about the chip supply chain.” While the benefits to solar are welcome, “this is a two-for-one.”
The Trump administration has signed a deal with RWE, a German developer, to cancel more than 3 gigawatts of offshore wind near New York and New Jersey.
This is an edition of Heatmap Daily, an evening review of the day’s news written by our executive editor. Sign up for it here.
There goes another one. The German energy developer RWE has signed a $1.2 billion deal with the Trump administration to give up its claims to develop offshore wind farms in New York, California, and Louisiana. The Trump administration has now bought out 12 offshore wind leases, paying energy developers $3.93 billion for the privilege of not developing renewable energy along the American coastline.
Today’s is the largest payout yet — and fittingly so, I suppose, because it is among the most damaging. As part of the deal, RWE abandoned its plans to build a more than 3-gigawatt offshore wind farm in the New York Bight. When RWE first leased that site in 2022, it paid $1.1 billion for it — the biggest offshore wind lease auction ever held in the United States.
RWE promised that the resulting facility, dubbed Community Offshore Wind, would generate 700 jobs and $3 billion in local economic activity. It would have been close enough to New Jersey and New York that its power could have flowed to either state, although no final power contract was ever signed. Now all of that is kaput.
In the eyes of some critics, RWE had overpaid for that lease — and in that context, the Trump administration has I suppose done the German developer a favor, bailing them out from a bad investment in a legally dubious manner. (New York’s attorney general is suing to block a similar payout to Total Energies.)
But even beyond that context, there remains one big problem with these deals — an issue even more glaring now than when Trump started targeting wind projects last year. It is that the United States — and especially the Northeast, and especially New York — needs as much electricity as it can get right now. The Trump administration is striving to bring new power demand online in the form of data centers, but cutting off new sources of generation if they fail to meet its aesthetic standards.
Anticipating this sensitivity, RWE’s press statement announcing the deal goes on to list major energy projects that it’s committed to in the United States. These projects all involve, coincidentally (or not), fossil fuels: They include a $900 million stake in a Louisiana liquified natural gas export terminal and a $300 million reservation for new natural gas turbines. (RWE implies, but doesn’t say outright, that it will build 15 natural gas peaker plants with these turbines.) When we asked for more details about these projects, and whether we should anticipate anything new, RWE immediately got back to us: “We are unable to discuss further details on the investments.”
Yet as RWE well knows, these projects won’t help solve a coming energy shortage in New York or New England. For one, the Louisiana LNG export terminal is, well, an export terminal: It will help move energy out of the country, not generate more of it at home. Those exports might boost Americans’ fortunes in a vague, long-term, balance-of-payments way, but they won’t keep a lid on anyone’s power bills (which, by the way, just hit an all-time high). More importantly, the 15 peaker plants that RWE cites are largely going to be built … in other regions of the country. If the lights go out on Houston Street, a new gas plant in Houston can’t help.
Americans paid $217 on average for electricity last month, according to Heatmap and MIT’s Electricity Price Hub.
July is typically the season of high electricity bills, and this year is no exception.
Nationally, the average electricity bill spiked to $217, an all-time high, according to new data from Heatmap and MIT’s Electricity Price Hub. That’s up from $177 in June, and $215 last July. Meanwhile, electricity rates were 19 cents per kilowatt-hour, virtually unchanged from June and slightly higher than July of last year.
Throughout the country, many ratepayers are seeing higher costs and charges in the portion of their bill covering the cost of power generation.
Once again, some of the most notable electricity price and bill trends were seen in the mid-Atlantic region, the heart of the data center boom and the anchor area of the PJM Interconnection. The region also includes Virginia, where Florida utility and energy developer NextEra is attempting to acquire the commonwealth’s dominant utility, Dominion.
In July, Dominion customers saw typical generation charges rise to $155 a month, up from $124 a year ago. Overall bills for Dominion customers were about $259 this past month.
The higher bills are in part due to the “fuel charge rider” that went into effect this past month to help recover about $1 billion in additional generation costs claimed by the utility. Those charges stem in part from higher fuel costs this past winter, when natural gas prices spiked to their highest level since the winter of 2022-23, Dominion officials said in a filing to the state’s utilities regulator. The MIT researchers estimate that the fuel charge added around $53 to July bills, up $12 from July of last year.
In neighboring Delaware, bills were $216 a month in July, a record high, while prices were around 19 cents per kilowatt-hour. Customers of the state’s main utility, Delmarva Power, saw a near 20% hike in the supply charge in their standard service offerings, as prices rose from around 16 cents per kilowatt-hour from last year.
The Delaware Public Service Commission voted at the beginning of last month to allow an interim rate increase of about $3 per month for the typical customer, which went into effect July 9. Soon after, Delaware Governor Matt Meyer signed a law giving the state’s regulators more discretion to reject putting certain utility costs into the rate base and thus limit subsequent price hikes requested by utilities. The governor’s office described the law as a mechanism “to prioritize prudent spending over unchecked cost recovery.”