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If the U.S. wants to compete on EVs, it will have to catch up to the rest of the world.

On Wednesday, the Biden administration finalized sweeping new rules that will sharply limit how much carbon pollution new cars and trucks can emit into the atmosphere. The rules — which rank as one of Biden’s most important climate moves — are aimed at accelerating the country’s transition to electric vehicles and plug-in hybrids, requiring most new cars sold in 2032 to burn little gasoline or none at all.
My colleague Emily Pontecorvo has an excellent explainer on how the new rules work. But I want to focus on one more aspect: Why they are able to do so much more than previous tailpipe regulations.
The new rules are not the Environmental Protection Agency’s first foray into regulating climate-warming pollution from vehicle tailpipes. Since 2010, the EPA has periodically tightened new limits on the amount of climate-warming pollution that cars and light-duty trucks can emit. The new rules are in some ways merely the next evolution of that approach.
But they also go much further than the agency ever has before. Where previous regulations essentially required automakers only to sell some conventional hybrids and electric vehicles, by the beginning of next decade, the lion’s share of cars sold in the United States must be electric vehicles or hybrids, the EPA now says.
Why is that ambition possible? One reason is that the United States has a more aggressive climate law on the books now than it has had during past rulemakings. Biden’s climate law, the Inflation Reduction Act, will subsidize the purchase, leasing, and manufacturing of electric vehicles. Because of how the EPA calculates the costs and benefits of its proposals, these subsidies will significantly cut the projected cost of even an ambitious rule — in this case by as much as $65 billion. (The agency calculates that consumers will save even more money — up to a staggering $230 billion — by paying less gasoline tax because they will be buying less fuel.)
Yet the IRA is not the only reason — or even the main reason — these rules can go so much further than what was previously imagined. If the United States can pursue such an ambitious standard now, that’s because it’s following on the heels of electric vehicle policy passed in other jurisdictions: China, California, and the European Union. These state and national policies have set the pace for the EV transition around the world, setting new market expectations or significantly cutting the costs of building an electric car.
They also created a sense of inevitability around electric vehicles. “The future is electric. Automakers are committed to the EV transition,” John Bozella, the president and CEO of the Alliance for Automotive Innovation, a car-industry trade group in Washington, said in a statement Wednesday on the EPA rules.
Corey Cantor, an analyst at the market research firm BNEF, summed it all up. “What is different this time — compared to say, where the world was in 2016 — is that there is now a thriving global EV market, versus a nascent one,” he said. There are also a handful of global companies poised to profit from a global EV transition, regardless of what Ford, Toyota, General Motors, and other legacy auto brands do.
Even before Biden asked the EPA to issue new regulations, in other words, these policies had changed the metaphorical game board — and changed how far the agency could push the rules.
These global policies don’t all take the same form. California and the European Union already require that all new cars sold in 2035 must be electric vehicles or plug-in hybrids, although the EU has carved out an exception for a theoretical zero-carbon gasoline replacement.
Due to a longstanding provision in the Clean Air Act, other U.S. states can opt into California’s stricter air pollution laws. So far, 14 in total — making up more than 40% of America’s light-duty car market — have adopted California’s 2035 zero-emissions vehicle mandate.
China, meanwhile, has not set a requirement that all cars must plug in by a certain year. Instead, it will require that “new energy vehicles” — a category that can include EVs and plug-in hybrids, but also conventional hybrids — must make up half of all car sales by 2035. But Chinese companies have raced ahead of this target. Wang Chuanfu, the CEO of the massive Chinese automaker BYD, estimated this weekend that 50% of China’s car sales could be new energy vehicles as soon as June.
All together, these mandates added up to a strong market signal. By last year, more than half of the global auto market was already covered by some form of clean vehicle rule — even before the EPA did anything final. Now, if the new EPA rules are enforced as written, then more than 60% of the world’s car market will be subject to some kind of emissions mandate.
This reflects, at least in part, a recognition that the global car market is changing beyond the ability of Washington politicians to influence it. “If we’re talking 10 years from now, policy probably won’t be needed, at least in leading markets. EVs will have just naturally taken over the market,” Stephanie Searle, who leads research programs at the International Council on Clean Transportation, told me.
Over the past year, a parade of cheap new EVs from Chinese automakers — including the BYD Seagull, a sub-$10,000 hatchback that gets up to 251 miles of range — have stunned the automotive industry. Jim Farley, the CEO of Ford, told investors last month that the company was reorienting its strategy to combat the rise of Chinese electric-car makers, such as BYD and Geely.
“If you cannot compete fair and square with the Chinese around the world, then 20% to 30% of your revenue is at risk,” Farley said at an industry conference last month. He disclosed that Ford had set up a secret internal “skunkworks” engineering team to make an affordable electric vehicle that could compete head-to-head with Chinese models on cost. The company has delayed the release of a new electric three-row SUV in order to produce three roughly $25,000 models, according to a Bloomberg report last week.
“Automakers see the future is electrified, and they see that Chinese companies will eat their lunch if they don’t get going,” Searle, the clean transportation researcher, said. “There’s no putting the genie back in the bottle.”
But China’s dominance was not inevitable — it was itself the result of ambitious industrial policies. Roughly 15 years ago, China identified the electric vehicle industry as a sector where it could eventually become a global leader in export markets, Benjamin Bradlow, a Princeton professor of sociology and international affairs, told me.
Since then, the country’s leaders have targeted the EV sector with generous subsidies far beyond what Americans lawmakers considered for the IRA, he said. They have also encouraged the EV industry’s geographic spread across China and required automakers to sell a certain percentage of EVs across their vehicle fleet.
“It’s a very different style of policymaking” from what America has done with the IRA, Bradlow said, although like that law it also aimed to lower the cost of technologies. “[China] is targeting a sector and it’s being very specific about being at the technological and price frontier — it’s very export-oriented.”
These policies have succeeded beyond imagining. China is now the world’s largest exporter of cars, and it has become a goliath in the EV industry. The country has achieved what hippies and renegades have long claimed is possible: a thriving and cutthroat electric vehicle industry, where consumers are willing to buy EVs without significant subsidies. (Indeed, China’s electric-car makers have been locked in a price war over the past year, driving even greater adoption as prices fall.)
These Chinese industrial policies — along with American and European-funded R&D — have cut tens of thousands of dollars from EV prices. Over the past three decades, the cost of manufacturing a battery has fallen by 97%, and by 2027 manufacturing a new EV battery is projected to cost less than $100 a kilowatt-hour, a long-theorized benchmark at which an electric vehicle will be competitive with a gasoline vehicle.
In the United States, mandates and subsidies in achieving mass EV adoption have not been quite as enthusiastically received. Some 7% of new cars sold in the United States last year were EVs, an all-time high. Plug-in and conventional hybrids made up an additional 8% of new car sales, according to the U.S. Energy Information Administration.
Those sales shares will need to double repeatedly in the years ahead for American automakers to meet the EPA’s new standards. And they point to at least one form of success that has alluded American policymakers so far: creating a robust, popular EV industry that can win over consumers on its own terms.
“The ultimate success of the policy and transition overall is a mix between policy, consumer adoption, and the automakers themselves,” Cantor, the BNEF analyst, told me.
For the first time ever, in other words, “automakers who fall behind may pay a far higher cost for failure to transition,” Cantor said. And that — above anything else — is what makes these EPA rules different from any that have come before.
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Plus a startup harvesting energy from roadways nabs a new funding round and more of the week’s big money moves.
Uncertainty may have dried up venture funding for early stage climate, but that doesn’t mean there aren’t still deals getting done — or past commitments now coming to light as funding rounds close. This week, for example, brings early-stage backing for a European startup working to convert wasted kinetic energy from braking vehicles into power at ports, as well as a software company helping utilities visualize and manage the increasingly complex electrical grid. Meanwhile, nuclear company Deep Fission proved that the private markets aren’t the only game in town — after going public via SPAC, it’s now planning to list its shares on the Nasdaq stock exchange.
There’s also some promising news for companies looking to scale up, with thermal battery company Antora turning on its first commercial plant in South Dakota this week. That project was made possible in large part by backing from one Australian billionaire. But there’s also S2G Investments, which last week closed a $1 billion fund focused on growth-stage companies and will perhaps help more climate technologies reach that critical commercial milestone.
Every day, hundreds of millions of vehicles travel the world’s roads, converting fuel into motion and exerting mechanical force on the roads’ surface. Much of that kinetic energy is shed as heat when a vehicle throws on the brakes to navigate curves, intersections, ramps, and traffic signals. Austria-based startup REPS plans to capture some of that wasted energy, raising $23.6 million to “turn roads into power plants” by embedding hydraulic plates into road surfaces in braking zones, converting a vehicle’s momentum into clean electricity.
The mechanism is straightforward: As cars and trucks drive over the plates, they compress hydraulic cylinders built into the system, generating pressure that drives an onsite generator. The resulting electricity is routed to on-site battery storage systems, where it’s put to use powering on-site operations or feeding directly back into the local grid, turning high-traffic roads, ports, industrial sites, and other logistics hubs into their own small power sources. The company claims that capturing the energy lost through traffic could account for about 5% of global electricity demand, at least in theory.
REPS isn’t the first to attempt this form of so-called "energy harvesting,” but it says past efforts have failed due to the inferior efficiency and durability of existing mechanical energy converters. The company says its proprietary system, however, can operate for over 20 years. It’s already got one commercial system up and running in the Port of Hamburg, and says that if it were to install hundreds of such systems around the port, costs could be recovered in under four years. Now the startup is engaging with ports around the world and looking to build installations in other logistics hubs and cities.
At the end of last year, I identified Deep Fission, a startup looking to build small nuclear reactors inside underground, water-filled boreholes, as one of the wackiest recent bets in climate tech. Now the company has announced plans to go public at a target valuation of roughly $1.7 billion, seeking to raise $156 million in the process. Its thesis is that placing car-sized, 15-megawatt reactors about a mile underground could dramatically reduce both costs and safety risks. The surrounding rock would effectively serve as a natural barrier and containment vessel, negating the need for many of the bulky structures typically required to house reactors and prevent radioactive leaks.
The planned Nasdaq listing comes less than a year after the company’s somewhat unusual SPAC merger, which listed Deep Fission on the lesser-known and lightly traded OTCQB stock exchange and netted just $30 million. According to an SEC filing, the stock never actually traded, and at the time of the offering, it read as a quick attempt to secure cash. The startup had been attempting to raise a $15 million seed round earlier in the year that never panned out, and to date has raised only a modest $4 million in venture funding.
Deep Fission’s fortunes might be shifting, however, given that it’s transferring its listing to a major national exchange. The company’s public markets strategy does appear to be working as of late — In February, the startup raised $80 million by selling over 5 million restricted shares directly to investors. Whether this will all be enough to achieve its goal of beginning commercial operations in 2027 or 2028 remains to be seen, however. As a part of the Department of Energy’s Reactor Pilot Program, Deep Fission initially aimed to reach criticality — the point at which a nuclear chain reaction becomes self-sustaining — by this July, a target that now looks highly unlikely.
As utilities scramble to keep pace with surging electricity demand, expanding grid-scale renewables, increasingly extreme weather while also coordinating new, distributed resources coming online, modern grid management is getting too complex for traditional software to keep up. Texture, the startup billing itself “the operating system for the energy grid,” wants to simplify the ecosystem by giving utilities, virtual power plant operators, and grid service companies a unified view of every device and associated data sources across their network — and it just raised a $12.5 million Series A to scale this solution further.
Texture’s software aggregates data from various sources — everything from smart meters to battery storage systems, electric vehicles, and smart thermostats — and consolidates it into a single layer for grid operators, flagging problems such as voltage irregularities or outage risks in real time. The platform sits atop an operator’s legacy software infrastructure, thus avoiding the need for utilities to overhaul their existing systems or implement customized and expensive enterprise solutions that require dedicated engineering teams to maintain.
The tech has gained traction among utility cooperatives — customer-owned nonprofits that often serve rural communities and maintain smaller staffs and tighter budgets than investor-owned utilities. With this latest raise, the startup is looking to access greater scale in the co-op market through a partnership with the National Rural Telecommunications Cooperative, a network of 850 utility cooperatives across the country which will now gain access to some of Texture’s software. As Texture’s CEO Sanjiv Sanghavi said about its co-op customers in the company’s press release, "They wanted to run modern grid programs but didn't have software built for their scale or budget. A co-op serving 15,000 members shouldn't have to build custom technology to launch a battery program or manage transformer load. We built Texture so they don't have to."
I was off last week, which means I missed the chance to bring you a piece of news that I’m particularly excited about: The sustainability-focused firm S2G Investments closed a $1 billion fund in what managing partner Aaron Rudberg described in a post on the firm’s website as “one of the most difficult fundraising environments in over a decade.” What’s more, this fund is specifically designed to help growth-stage companies bridge the persistent capital gap that emerges for climate tech companies after early-stage venture rounds but before institutional investors deem them bankable. This void often prevents startups from building first-of-a-kind facilities or deploying their solutions broadly enough to prove out their tech and drive down costs.
This fund is also a milestone for S2G itself, marking the firm’s first close after spinning off two years ago from Builder’s Vision, a family office managing investments for Walmart heir Lukas Walton. According to Rudberg, the fund is writing checks in the $25 million to $100 million range, and has already invested $300 million across 10 companies, largely in food and agriculture, energy, and ocean systems. The various recipients include the agricultural input startup Exacto, maritime battery supplier Echandia, and the industrial power optimization company ANA, Inc.
So-called missing middle financing is difficult precisely because it often involves technologies that, at least initially, carry a green premium or depend on policy support. But S2G is adamant that there are plenty of competitive startups, even in a political environment where climate policy is on the outs and affordability is a top concern.
“We believe some of the most attractive investment opportunities are in growth-stage businesses that deliver economic superiority through improved efficiency, margins, and resilience in industries fundamental to the global economy,” Rudberg wrote, as companies with unfavorable economics are being weeded out. “What remains are businesses with genuine commercial advantage, and those are the companies this Fund is built to back.”
Bonus: Antora Turns On Colossal 5 Gigawatt-Hour Thermal Battery in South Dakota
Over two years ago, I wrote about how super hot rocks — that is, thermal batteries — were one of the coolest things in climate tech. Since then, the companies I profiled, Rondo Energy and Antora Energy, have both brought their first commercial plants online, with the latter reaching that milestone this week. On Tuesday, as we covered in Heatmap AM, Antora turned on its 5 gigawatt-hour project in South Dakota, which stores excess wind power as heat for a bioethanol plant operated by POET, the world’s largest biofuel producer. Once the facility ramps to full capacity later this year, it will rank among the world’s largest energy storage projects, relying on over 200 of Antora’s thermal batteries.
Antora’s tech works by absorbing surplus wind power that would otherwise go to waste in windy South Dakota, where generation often outpaces what the region’s congested transmission lines can handle. The startup converts that renewable electricity to heat using resistive heating, essentially the same technology as a toaster. That’s then stored in insulated carbon blocks for later use, where it can be delivered as direct heat to power high-temperature industrial processes, or converted back into electricity. In this case, the heat is transferred to a circulating fluid that carries it to the POET plant, where it’s then delivered as steam to power boilers, distillers, and other machinery used in ethanol production.
Neither POET nor Antora have disclosed the value of this long-term offtake agreement. The sole external investor providing project-level financing was Australian firm Grok Ventures, a climate-focused investment company bankrolled by Mike Cannon-Brookes, co-founder and CEO of enterprise software company Atlassian. One of Australia’s richest people, Cannon-Brookes has emerged as one of world’s foremost climate investors, pledging $1.5 billion of his wealth to climate projects by 2030. Perhaps its telling of the investment environment at large that an Australian billionaire — rather than the U.S. government or institutional investors — had to push this first-of-a-kind project over the finish line.
On Exxon’s Venezuela flipflop, SpaceX’s fears, and a nuclear deal spree
Current conditions: U.S. government forecasters project just one to three major storms in the Atlantic this hurricane season • The Meade Lake Complex, a wildfire that scorched 92,000 acres in southwest Kansas, is now largely contained • Temperatures in Vientiane, the sprawling capital of Laos, are nearing 100 degrees Fahrenheit amid a week of lightning storms.
A years-long megadrought. Reduced snowpack in the northern mountains. Rising water demand from southwestern farms and cities whose groundwater is depleting. It is no wonder the water levels in Lake Mead are getting low. Now the Trump administration is giving the Hoover Dam money for a makeover to make do in the increasingly parched new normal. The Great Depression-era megaproject in the Colorado River’s Black Canyon boasts the largest reservoir capacity among hydroelectric dams. But the facility’s actual output of electricity — already outpaced by six other dams in the U.S. — is set to plunge to a new low if drought-parched Lake Meade’s elevation drops below 1,035 feet, the level at which bubbles start to form damage the turbines. At that point, the dam’s output could drop from its lowest standard generating capacity of 1,302 megawatts to a meager 382 megawatts. Last night, federal data showed the water level perilously close to that boundary, at 1,052 feet. The Bureau of Reclamation’s $52 million injection will pay for the replacement of as many as three older turbines with new, so-called wide-head turbines, which are designed to operate efficiently at levels below 1,035 feet. Once installed, the agency expects to restore at least 160 megawatts of hydropower capacity. “This action ensures Hoover Dam remains a cornerstone of American energy production for decades to come,” Andrea Travnicek, the Interior Department’s assistant secretary for water and science, said in a statement.
Like geothermal, hydropower is a form of renewable energy that President Donald Trump appreciates, given its 24/7 output. Last month, the Department of Energy’s recently reorganized Hydropower and Hydrokinetic Office announced that it would allow nearly $430 million in payments to American hydropower facilities to move forward after stalling the funding for 293 projects at 212 facilities. Last year, the Federal Energy Regulatory Commission proposed streamlining the process for relicensing existing dams and giving the facilities a categorical exclusion from the National Environmental Policy Act. The Energy Department also withdrew from a Biden-era agreement to breach dams in the Pacific Northwest in a bid to restore the movement of salmon through the Columbia River.
Shortly after the U.S. capture of Venezuelan leader Nicolas Máduro in January, Exxon Mobil CEO Darren Woods told CNBC the South American nation would need to embark on a serious transition to democracy before the largest U.S. energy company could invest in production in a country the firm exited two decades ago amid the socialist government’s crackdown. Five months later, he may be changing his tune. On Thursday, The New York Times reported that Exxon Mobil was in talks to acquire rights to start drilling for oil in Venezuela. If finalized, such a deal would mark what the newspaper called “a victory for President Trump, who has declared the country’s vast natural wealth open to American businesses.”
It’s not just Elon Musk’s xAI data centers that brace for the data center backlash that Heatmap’s Jael Holzman clocked last fall as the thing “swallowing American politics.” In its S-1 filing to the Securities and Exchange Commission ahead of one of the country’s most anticipated stock market debuts this year, SpaceX warned that mounting public skepticism over AI could harm the growth of America’s leading private space firm. “If AI technologies are perceived to be significantly disruptive to society, it could lead to governmental or regulatory restrictions or prohibitions on their use, societal concerns or unrest, or both, any of which could materially and adversely affect our ability to develop, deploy, or commercialize AI technologies and execute our business strategy,” the company disclosed in the filing, a detail highlighted in a post on X by Transformer editor Shakeel Hashim. “Our implementation of AI technologies, including through our AI segment’s systems, could result in legal liability, regulatory action, operational disruption, brand, reputational or competitive harm, or other adverse impacts.”
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Yesterday, I told you that corporate energy buyers last year inked deals for more nuclear power than wind energy. But if you needed more proof that, as Heatmap’s Katie Brigham called last summer, “the nuclear dealmaking boom is real,” just look at this week:
Separately, this week saw two projects take big steps forward:
It’s been the year of Chinese automotives. Ford’s chief executive admits he can’t get enough of his Xiaomi SU7. Chinese auto exports are booming. And now Beijing’s ultimate automotive champion, BYD, is accelerating talks to enter Formula 1. On Thursday, the Financial Times reported that the company had met with former Red Bull Racing chief Christian Horner in Cannes. “Following talks between Stella Li, executive vice-president at BYD, and Horner last week, BYD intends to hold further meetings with senior figures involved in F1 and at the FIA, the governing body,” the newspaper reported.
China’s hydrogen boom continues. The country’s electrolyzers are quickly going the way of batteries and solar panels by securing global export deals that reflect their efficiency and competitive prices. On Thursday, Hydrogen Insight reported that Chinese manufacturer Sungrow Hydrogen inked a deal to supply a 2-megawatt alkaline electrolyzer to a Spanish cement facility. That same day, another Chinese manufacturer, Hygreen Energy, announced an agreement to supply a 1.3-megawatt system to a green hydrogen project in Nova Scotia.
With both temperatures and electricity prices rising, many who are using less energy are still paying more, according to data from the Electricity Price Hub.
In 135 years of record-keeping, Tampa, Florida, has never been hotter than it was last July.
Though often humid, the city on the bay is typically breezy, even in summer. But on July 27, it broke 100 degrees Fahrenheit on the thermometer for the first time ever; two days later, it hit its highest-ever heat index, 119 degrees. The family of Hezekiah Walters, the 14-year-old who died of heat stroke during football practice in Tampa in 2019, urged neighbors at a local CPR certification event to take the heat warnings seriously. Local HVAC companies complained about the volume of calls. Area hospitals struggled to keep their rooms and clinics comfortable. Experts later said the record temperatures were made five times more likely by climate change.
But according to data from Heatmap and MIT’s Electricity Price Hub, Tampa Electric customers used 14% less electricity in July 2025 than they did in the same month of 2020, which was Tampa’s previous hottest July on record — about 216 kilowatt-hours per household less, roughly the equivalent of running a central AC a couple hours fewer per day for an entire month. Tellingly, Tampa Electric raised rates over that period by 84%, with the average bill growing from $111 to $190 per month.
Though there are many instances in many places around the country where usage has dropped as rates rose, the correlation doesn’t necessarily mean people were rationing their electricity. Climate-related factors like anomalously cool summers can lower summer bills, while energy efficiency upgrades can also result in changes to residential consumption. Southern California Edison customers, for example, used 24% less electricity in 2025 than they did in 2020, at least in part due to the widespread adoption of rooftop solar.
Thanks to recent efforts by the Energy Information Agency to track energy insecurity and utility disconnections, however, we can start to tease out deficiency from efficiency. By cross-referencing that data with rate and usage statistics from the Electricity Price Hub, we find a handful of places like Tampa, where people have seemingly reduced their electricity usage because they couldn’t afford the added cost, even during a deadly heatwave. (Tampa Electric did not return our request for comment.)
The EIA’s tracking program, known as the Residential Energy Consumption Survey, tells a clear story: Across the country, people are struggling to absorb the rising costs of electricity. In 2020, nearly one in four Americans reported some form of energy insecurity, meaning they were either unable to afford to use heating or cooling equipment, pay their energy bills, or pay for other necessities due to energy costs. By 2024, the most recent data available, that number had risen to a third — and two-thirds of households with incomes under $10,000. In 2024 alone, utilities sent 94.9 million final shutoff notices to residential electricity customers.
Since 2020, 98% of the more than 400 utilities in the Heatmap-MIT dataset have raised their rates — more than half of them by greater than 20%; about one in 10 utilities have raised their rates by 50% or more. And 219 of those utilities raised rates even as usage in their service area fell, meaning that as customers used less, they still paid more.
“I don’t feel like [the rates have] ever been all that affordable, but they have steadily increased more and more and more,” Janelle Ghiorso, a PG&E customer in California who recently filed for bankruptcy due to the debt she incurred from her electricity bills, told me. She added: “When do I get relief? When I’m dead?”
The people hit hardest by rate increases tend to be those already struggling the most. For example, about 30% of Kentucky residents reported going without heat or AC, leaving their homes at unsafe temperatures, or cutting back on food or medicine to pay energy bills, per the EIA’s 2020 RECS report. Since then, Kentucky Power has raised rates in the eastern part of the state by 45%, adding about $64 to the average monthly bill in a service area where the median monthly household income can be less than $4,000.
The Department of Energy’s Low-income Energy Affordability Data, which measures energy affordability patterns, actually obscures some of this burden. It reports that for all of Kentucky, annual electricity costs account for about 2% of the state’s median household income, which is about average for the nation. But in Kentucky Power’s Appalachian service area specifically, many households live under 200% of the poverty level, and $15 of every $100 someone earns might go toward their energy costs, Chris Woolery, the residential energy coordinator at Mountain Association, a nonprofit economic development group that serves the region, told me. “The situation is just dire for many folks,” he said.
Kentucky Power is aware of this; its low-income assistance charge has grown by 110% since 2020, the Heatmap-MIT data shows. Woolery also noted that the utility agreed to voluntary protections against disconnections, such as a 24-hour moratorium during extreme weather, in a rate case settlement with the Kentucky Public Service Commission. The commission rejected the proposal, but the utility kept the protections anyway, Woolery told me.
Customers in other areas are not so lucky.
In states like Oklahoma, where one in three households reported energy insecurity in 2020, rates rose about 30% from 2020 to 2025, according to our data. Per the EIA survey, Oklahoma’s monthly disconnection rate is more than three times the national average. Oklahoma doesn’t have the highest electricity rates in the country — far from it. But median incomes there are low enough that even moderate rate increases leave some with hard choices.
Interestingly, in bottom-income-quartile states, where median household incomes are below $81,337, only about 30% of utilities show a pattern of rising bills and falling electricity usage, which would suggest energy rationing. The other 70% of utilities show the opposite effect: usage is rising despite electricity rates becoming a bigger burden of customers’ incomes. In Kentucky Power’s service area, for example, bills may be up $64 a month, but usage remained essentially flat.
“Think of it this way: The electric company goes to the front of the line,” Mark Wolfe, the executive director of the National Energy Assistance Directors Association, a policy group for administrators of the Low-Income Home Energy Assistance Program, told me of how households triage their bills. If you need to buy something from the grocery store, the drug store, or pay your electricity bill, then “the utility goes to the front of the line because they can shut off your power, which causes lots of other problems.”
Wolfe added, “Plus, if you’re really in dire straits, you can go to the food bank. You can’t go to the ‘other’ utility company.”
Even as resource-strapped households put a higher share of their income toward electricity, they’re also least able to afford energy efficiency upgrades like newer appliances, smart thermostats, or solar panels. The pattern is prevalent in places with extreme climates, such as Louisiana, Mississippi, and Alabama, where turning off the AC in the middle of summer could mean death. It shows up most starkly among the most extreme rate examples in our data set, like the utilities serving remote Alaska villages — despite astronomical electricity prices, usage hasn’t fluctuated much because its customers are already using it as little as they can afford. The elderly and other individuals living on fixed incomes are also often unable to cut their electricity usage beyond what little they’re already using.
In middle-income states like Florida, roughly 60% of the utilities in our dataset show rising bills and falling electricity use — more than twice the rate we see in the lowest-income states. While the poorest Americans have already reduced their electricity use to the bare minimum and are cutting groceries and medicine in order to keep the heat and AC on, in places like Tampa, where the median income is $96,480, the electricity rate shocks have caused even middle- and even high-earning households to start worrying about their bills. According to a new survey released Tuesday by Ipsos and the energy policy nonprofit PowerLines, 74% of respondents with household incomes over $100,000 said they are worried about their utility bills increasing.
“People are seeing their utility bill as one of the few things that changes so much month to month, that is so unpredictable, and that they don’t have any control over,” Charles Hua, the founder and executive director of PowerLines, told me.
Wolfe, the executive director at NEADA, agreed, saying that for the first time, the association has begun hearing from families with incomes above the threshold who need assistance. “An extra $100 a month for a family, but they’re middle class — that shouldn’t push them over the edge,” at least in theory, Wolfe said. But for those with no flexibility in their budgets, anything additional or unpredictable “pushes them close to the edge — from going from middle class to lower middle class — and I think that’s why this affordability crisis is becoming such an issue.”
We can also see this phenomenon in the explosion of line items on utility bills going toward funding assistance programs. Appalachian Power Co.’s low-income surcharge, for instance, is up 3,200% for customers in Virginia; Puget Sound Energy’s low-income program is up 970% for customers in Washington; and PacifiCorp Oregon’s low-income cost-recovery charge, up 879%.
The EIA data, too, bears this out: Florida had one of the highest rates of people reporting they were “unable to use air conditioning equipment” due to costs in the RECS data, and in 2024, there were 186,202 disconnections in the state in July alone — every one of which would have meant people no longer had the power to run their ACs. (FPL and Duke Energy Florida also show usage declines as rates rose, although neither raised rates as much as Tampa.)
The data also shows places where higher-income earners have aggressively pursued efficiency upgrades to lower their usage. In the LA Department of Water and Power service area in California, usage is down more than 11% overall between 2020 and 2025, one of the biggest drops in our dataset. But the lower usage is more evenly distributed month to month, indicating that things like solar adoption and efficiency programs are likely behind the drop, rather than cost pressures. (Rates there still rose more than 28%, or about $15 per month.)
Even doing everything right wasn’t enough to save customers in the end — households that cut their electricity use still saw their bills rise by an average of $20 a month, our data shows.
Perhaps most concerning, though, is the relentless upward trajectory. PowerLines reports that utilities have submitted $9.4 billion in new requests in the first quarter of 2026 alone. Heatmap and MIT’s numbers show that 79% of utilities raised rates in 2025, and 55% have raised them again already this year.
But the advocates I talked to stressed that utilities have more agency than they get credit for. Take Kentucky Power, for example, with its voluntary disconnection protections. “It just shows that you don’t necessarily have to make disconnections to be financially solvent,” Woolery of the Mountain Association pointed out. Or take Ouachita Electric in Arkansas, which passed a 4.5% rate decrease after investing in efficiency upgrades in consumers’ homes through a pay-as-you-save model.
But that’s the rare exception. For most customers, relief is not obviously on the way. Signs increasingly point to the imminent onset of a super El Niño, which could bring punishing, climate-change-intensified heat waves across the United States. The July 2025 record in Tampa will almost certainly not stand; someday, it’ll be the second-hottest summer, or the third. In a few decades, it might even look cool.
And still there will be bills to pay.