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On solar growth, Hornsea 4, and Rivian deliveries

Current conditions: The first cicada broods have begun to emerge in the Southeast as soil temperatures hit 64 degrees Fahrenheit • Hail and even snow are possible across parts of Spain today • Forecasters have identified a risk zone for tropical storm development in the Atlantic basin, with potential for the first named storm of the year to form by mid-May.
1. Global solar market expected to slow in 2025
The global solar market is expected to grow only 10% in 2025, down from 33% growth in 2024 and 87% growth in 2023, according to a new report by SolarPower Europe. The firm’s “most realistic scenario” accounts for the natural slowdown in development after a boom caused by high energy prices in 2022 and 2023, as well as the “uneven distribution of solar market growth” worldwide, with China accounting for 55% of the market share, lending to the dip in overall solar as it implements reforms this summer in how its renewables are priced and traded.
Speaking at the opening of the Intersolar 2025 conference in Munich on Wednesday, Abigail Ross Hopper, the CEO of the Solar Energy Industries Association, echoed some of the uncertainty expressed in SolarPower Europe’s report. “I don’t think any of us could be in this business if we weren’t optimistic,” she said, adding, “I think we’re going to weather through this storm, but it is going to be a bit rocky for a few years.” SolarPower Europe’s report, meanwhile, anticipates “likely” growth from 2 terawatts of global installed solar capacity at the end of 2024 to 7.1 terawatts of total installed capacity by 2030, which would meet “nearly two-thirds of the 11 terawatt renewable energy target set at COP28.” Under ideal conditions, solar could even quadruple capacity to more than 8 terawatts by the decade’s end. Read the full report here.
2. Orsted cancels 2.4-gigawatt offshore wind project in the UK, citing rising costs
The Danish energy company Orsted announced this week that it is canceling its Hornsea 4 offshore wind project in the UK due to rising supply chain costs and other “adverse macroeconomic developments,” the Wall Street Journal reported Wednesday. Hornsea 4 was expected to become one of the biggest offshore wind farms in the world, with a capacity of 2.4 gigawatts once it was completed. (Equinor’s recently paused Empire Wind I project, south of New York’s Long Island, would have had an 810-megawatt capacity by comparison.)
Orsted warned it would take a hit from the cancellation, with breakaway costs estimated to be between $533 million and $685 million. Nevertheless, “Orsted said the project no longer made economic sense, even with a contract to sell power at government-guaranteed prices for 15 years,” Bloomberg writes. Significantly, the canceled project will also hurt the UK’s efforts to add more renewables to its power grid.
3. ICYMI: Rivian lowered its delivery estimate by as much as 15% due to tariffs
Rivian beat Wall Street’s first quarter estimates, the automaker shared in its earnings letter to investors on Tuesday, but lowered its target for 2025 vehicle deliveries on account of tariffs, CNBC reports. Though the company builds all its electric vehicles in Illinois, “The current global economic landscape presents significant uncertainty, particularly regarding evolving trade regulation, policies, tariffs, and the overall impact these items may have on consumer sentiment and demand,” Rivian said by way of explanation. While it previously estimated it would deliver between 46,000 and 51,000 units in 2025, the revised outlook anticipates 40,000 to 46,000 deliveries. Last year, the company delivered just over 51,500 vehicles, Inside EVs notes.
The company also said it expects to take on “a couple thousand dollars” in additional expenses per vehicle due to the trade policies, though founder and CEO R.J. Scaringe said it’s not planning to increase the $45,000 starting price of the R2 as a result. Despite the continued uncertainty, Rivian said it still expects to achieve a “modest positive gross profit” in 2025.
4. Republicans sneak sale of public lands into reconciliation bill
Republicans on the House Committee on Natural Resources added an eleventh-hour amendment to their portion of the budget package late Wednesday night, calling for the sale of thousands of acres of public lands in Nevada and Utah. Introduced by Representatives Mark Amodei of Nevada and Celeste Maloy of Utah, the provision capitalized on longtime aspirations by Republicans to privatize Bureau of Land Management acreage in the West.
As I wrote on Wednesday, the Republicans’ maneuver, “which came at nearly midnight, left many Democrats and environmental groups deeply frustrated by the lack of transparency,” and critics had little time to comb through the extent of the proposal. While early reviews of the bill estimated the sell-off of about 11,000 acres of land, much of it apparently near cities — in keeping with Republican Senator Mike Lee’s aspirations to use BLM land for suburban sprawl — the Wilderness Society informed me last night that the accounting may end up as high as 500,000 acres or more. That’s consequential not just for public land advocates, but also because “turning over public lands to states — or to private owners — could ease the way for expansive oil and gas development, especially in Utah, where there are ambitions to quadruple exports of fossil fuels from the state’s northeastern corner,” I note in my piece. Moreover, “Reducing BLM land could also limit opportunities for solar, wind, and geothermal development.”
5. Thinning forests to reduce wildfire danger could also mitigate droughts: study
Thinning forests is a favorite idea of Republicans, who’ve rebuked blue states over forestry practices they claim exacerbate the dangers of wildfires. Now, a new study from researchers at the College of Agriculture, Biotechnology & Natural Resources at the University of Nevada, Reno looking at the hydrology of the Sierra Nevadas has found that the practice — along with prescribed fires — could also have potential upsides during drought years, including generating more mountain runoff.
According to the findings published in the journal Water Resources Research, water yields in forests thinned to densities closer to those of a century ago can be increased by 8% to 14% during drought years. That water would be “particularly valuable … to farmers and cities in central California and northern Nevada who rely on Sierra [Nevada] snowpack for much of their water supply,” according to a press release about the research. Significant flooding risks did not appear to increase with the water yields. As earlier researchers have found, however, the results of forest thinning treatments also depend on how, where, and to what extent the treatments are applied. Not all landscapes would necessarily benefit from such regimes. For example, while President Trump blamed the January fires in Los Angeles on poor forest management in California, the blazes were in chaparral, not in forests where thinning could be applied.

University of California, Riverside announced Wednesday that it is launching the nation’s only hydrogen-powered carshare program in a partnership with city and state agencies. Participants can rent Toyota Mirai sedans through a smartphone app and pay hourly rates competitive with Uber and Lyft fees.
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The problem isn’t just affordability, two researchers from Heatmap and MIT’s Electricity Price Hub argue. Bill volatility also creates pain for electricity consumers.
Americans have come to expect shocking electricity bills, especially in the summer months. The latest data from the Electricity Price Hub makes clear: Households in every region of the country are seeing not just record high July bills, but also bills that are sharply higher than even just a few months before.
Some may see these trends and argue that utilities and regulators set rates, but bills are ultimately the result of consumer choices about how much electricity to use. But that narrative misses the mark for a simple reason: How utilities and regulators design rates influence both summer bill swings and how much electricity consumers use. Seasonal rates and other features of electricity pricing can exacerbate summer bill swings and inform customers’ decisions about whether certain electricity uses — even running the air conditioner on an extremely hot day — are worth it.
The scale of this summer’s electricity bill increases is striking. Nationwide, the average household electricity bill was $90 per month, or 71% higher in July than it was in April of this year. Not only are bills up, they are up from a high base. The national average bill in April 2026 was higher than any previous April average in the Electricity Price Hub data, and 37% higher than the national average in April five years ago.
These trends are not just driven by a few states. There are households in every corner of the country experiencing sharp increases in their power bills this summer.
At the state level, average household bills have increased the most in New Jersey (up 163%), Nevada (157%), and Oklahoma (133%), but bills have at least doubled in 11 states and are up 1.5 times in 24 more.
In 19 different states, average household bills from major utilities at least doubled from April to July, adding between $72 and $214 per month to their average customers’ bills. In 12 of those states — including some in the Northeast, Mountain West, South, and Southeast — more than 40% of all households are served by utilities whose average bills have at least doubled this summer.
Greater electricity use is a big part of what’s at play in these trends, but it’s not the whole story. Higher summer rates also contribute, in many cases. Rate design, market conditions, and regulatory processes can all cause electricity prices to change throughout the year.
Some utilities, for instance, have rates that vary seasonally, automatically adjusting in the summer months. Seasonal rates contribute to summer bill increases for eight of the 10 utilities whose average bill increased most from April to July. For three of those utilities, over half of the April-to-July increase was driven by seasonal rates. For another five, seasonal rates play a meaningful role, compounding usage-driven increases. For only two does the increase come back to usage alone.
Taken together, these findings suggest that summer bill shocks are not simply a function of warmer weather. In many cases, they also reflect deliberate choices about how utilities price electricity during the summer months.
Even where higher usage is the primary driver of rising summer bills, the way utilities structure rates influences how much customers can save by using less electricity or shifting when they consume power.
Across the utilities with the largest April-to-July bill increases, there is considerable variation in how they calculate a customer’s monthly bill. All include a mix of fixed monthly fees and charges based on usage, measured in dollars per kilowatt-hour. But the balance between these components differs significantly, with fixed charges contributing from 4% to 23% of average bills over the past 12 months. Some utilities apply the same per kilowatt-hour rate year-round, while others increase rates in the summer. For some, the same rate applies to the total amount of electricity customers use in a month, while others have rates that increase for higher tiers of usage.
That means the design of residential rates also determines how much households actually benefit from using less electricity. Two households may receive similar-sized bills, but depending on how their utilities structure their rates, customers can see very different savings from cutting back.
The three New Jersey utilities in the top 10 illustrate one approach: They all have relatively small fixed customer charges, along with per-kilowatt-hour rates that vary both seasonally and by usage tier. For example, Jersey Central Power & Light’s distribution charge shifts from a single volumetric charge in the winter to a tiered structure in the summer, with usage above 600 kilowatt-hours priced at a higher rate. This structure contributes to sizable seasonal bill swings, but it also creates a strong financial incentive to limit summer usage.
The average household in JCP&L’s service area used more than 1,000 kilowatt-hours in July 2025. Had that household used 15% less electricity, it would have saved roughly $50 that month; a 25% reduction would have saved $82. At current rates, a 25% reduction in usage would cut the average bill by 28%, and every 4 kilowatt-hour reduction in usage over 600 kilowatt-hours saves a dollar.
Nevada Power takes a different approach. Its residential rate consists of a larger fixed customer charge — contributing 14% of total average bills over the last year — and a set of volumetric rates that do not vary by season or usage level. As a result, consumers have less of a financial incentive to reduce consumption. A household would need to reduce usage by roughly 8.4 kilowatt-hours to save a dollar, and cutting electricity use by 25% would reduce the bill by about 23% — meaningfully less than under JCP&L's structure.
While seasonal variability in bills is expected and not on its face problematic, it is important to recognize that unpredictability and month-to-month volatility in power bills can compound energy affordability challenges. And although regulators cannot control the weather, the choices they make about rates influence the agency households have in managing their bills each month.
This then raises the question: Should utilities and regulators consider bill stability and its impact on affordability in setting rates? Staff for the Arizona Corporation Commission, which is currently considering requests from the state’s two investor-owned utilities to raise average household bills by around 15%, recently testified that “affordability and energy burden are not pertinent to ratemaking” — that they are, instead, “societal issues.” But that is exactly the wrong sentiment.
Affordability and bill stability both deserve to be explicit considerations in ratemaking, carefully weighed against other objectives and not dismissed or treated as an afterthought. Doing so may look different in different places and does not require prioritizing bill stability over all else. But where households are struggling to manage unpredictable power bills, regulators should be sensitive to those trends and lend greater weight to measures that boost households’ ability to manage usage and limit bills, should they choose to.
That may mean more effective and targeted energy efficiency and demand response programs and incentives for utilities to promote uptake. In some cases, it may call for better customer education on available rate schedules and ways to manage bills, and ultimately it may require more modern rate design. Whatever the response, stability is part of affordability. Wild bill swings add to the burden of record-high bills — a fact that utilities and regulators cannot afford to ignore.
On Trump’s mineral deals, the gas turbine backlog, and Turkic offshore wind
Current conditions: Tropical Storm Lala could strengthen into a hurricane before hitting Hawaii’s Big Island, becoming the first such storm to make landfall there since 1900 • A glacial outburst at Suicide Basin near Juneau, Alaska, is raising the Mendenhall River • Temperatures surpassed 107 degrees Fahrenheit in Zaragoza, the inland capital of Spain’s Aragon region.

The United States is rapidly approaching a two-decade streak as the world’s No. 1 producer of natural gas. The country held the top spot between 2009 and 2024, the latest year for which the U.S. Energy Information Administration has data. But America pumped record volumes of natural gas last year. And now the federal energy research agency forecasts 2026 will be another record year. Marketed natural gas production — the total volume that actually makes it to market, minus what’s burned off or leaks as waste — is set to reach an average of 122.5 billion cubic feet per day in 2026, up from 2025’s record of 118.5 billion cubic feet per day. The new milestone is the result of expanded drilling in the Permian region that straddles Texas and New Mexico, and in the Haynesville area, between Texas and Louisiana.
When the Trump administration first started buying up equity stakes in mining companies, former officials from the Biden administration told my colleague Matthew Zeitlin they were “jealous” that the Republican White House had the guts to try something novel to compete with China on the metals needed for defense and energy technologies. Now, however, top Democrats are asking federal watchdogs to probe whether the American taxpayer is actually getting good deals. New Mexico Senator Martin Heinrich, the ranking member of the Senate Energy and Natural Resources Committee, and Representative Jared Huffman, the top Democrat on the House Natural Resources Committee, called on the Government Accountability Office to open an investigation into potential conflicts of interest. In a letter sent last week to Acting U.S. Comptroller General Orice Williams Brown and published Thursday on E&E News, the lawmakers accused the White House of violating rules to assess the financial risk of federal purchases. “These equity acquisitions also create potential conflicts of interest for federal agencies because a significant portion of the planned mining operations are located on federal lands,” they wrote. “With the executive branch now holding direct financial equity in these private mining operations, the federal government is required to act simultaneously as a mining investor and land-use regulator, an inherent conflict of interest.”
Mitsubishi’s backlog of orders for large-frame gas turbines is now more than twice its output from last year. In the 2025 fiscal year, the Japanese industrial giant delivered 16 gigawatts of gas turbines and had a backlog of 23 gigawatts. Just halfway through 2026, that backlog has ballooned to 35 gigawatts, executives told investors on the latest quarterly earnings call. The update, announced in Japan last week and covered in English by Utility Dive on Thursday, shows that “demand for large-frame gas turbines remains broadly in line with, or slightly above, the strong level we had anticipated,” Hiroshi Nishio,the chief financial officer of Mitsubishi Heavy Industries.
Power electronics maker Heron Power, meanwhile, unveiled plans for a $100 million factory in Morgan Hill, California. The startup, led by a former Tesla executive, aims to produce next-generation transformers that can patch more solar panels and batteries on the grid and help ease some of the issues that arise from the direct current-based electricity sources. The first factory is designed to churn out 40 gigawatts of Heron Links, the transformer product, per year. “America's grid has to grow faster than it has in decades. We’re seeing new demand from AI and EVs, and at the same time new supply from solar and storage,” Drew Baglino, Heron Power’s chief executive and founder, said in a statement. “The equipment running the grid hasn’t changed in 50 years. Heron Factory One in Morgan Hill is how we fix that. We’re manufacturing the leapfrog technology our grid needs, at scale, in America first.”
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Offshore wind is in retreat in the U.S., where, as my colleague Robinson Meyer wrote this week, the Trump administration is paying billions to kill projects that were already dead or dying. The industry’s tide is also ebbing in Japan, where the new right-wing government of Sanae Takaichi is putting a heightened focus on nuclear power. Elsewhere, however, offshore wind is booming. Europe is only expanding its plans. China is steadily dominating the industry. And East Asian countries such as South Korea and Taiwan are expanding their sectors.
Now two of the richest countries in the Turkic world are laying plans for more offshore turbines. Turkey announced plans this week for its first offshore wind tender in the first quarter of 2027, Renewables Now reported. Azerbaijan, meanwhile, this week formally designated a 275-square-mile section of water in the Caspian Sea for offshore wind development, per offshoreWIND.biz. The moves highlight the extent to which the U.S. government stands alone in its view that offshore wind has no role in a modern electricity mix. Turkey, after all, is doubling its domestic production of gas and completing its first nuclear plant. Azerbaijan is famously rich in natural gas and produces a decent amount of hydropower. Yet both countries are still charging ahead on offshore wind.
Deep-sea mining isn’t yet technically legal in international waters. But the Trump administration isn’t waiting, creating the regulatory frameworks for domestic approvals and opening the area around one of America’s Pacific territories to exploration. Japan has been eager to follow suit. Now Washington and Tokyo are planning to meet “centuries’ worth of industrial demand” by establishing what Mining.com called the world’s deepest undersea mine in a bid to take on China’s mineral dominance. The mineral extraction would take place more than 1,000 miles southeast of Tokyo on an uninhabited speck of land called Minamitorishima, where Japanese scientists carried out tests pulling rare earths out of mineral-rich mud.
China is actively building more reactors at home than all other countries combined and singlehandedly restarted the race for novel technologies after hooking the world’s only commercial high-temperature gas-cooled reactors up to the grid in 2023. So far, Beijing’s two state-owned nuclear companies have remained focused on building light water reactors. Just one new high-temperature gas-cooled unit, designed to have more than twice the output of the first version, is currently underway at a facility where the fourth-generation, helium-cooled technology will be paired with third-generation, water-cooled reactors. Now the developer, the China National Nuclear Corporation, has made plans to procure a contract for the reactor for the first time, laying the groundwork for future deals to purchase units specifically designed to reach high temperatures. The “first concrete” for the plant is expected to be poured by the end of 2026, World Nuclear News reported.
Investment in zero-carbon energy and transportation surged this spring, driven by consumer EV and battery buying.
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.
Ready to be surprised? Clean energy and transportation investment surged in the second quarter of this year, rising to more than $75 billion in total, according to new data released earlier this week.
In fact, this spring was the second biggest quarter for U.S. clean investment in nominal terms since at least 2018, when data started to be kept. More than 5% of overall investment in the United States went into a clean energy or transportation industry.
That’s according to the Clean Investment Monitor, a joint project of the MIT Center for Energy and Environmental Policy Research and the Rhodium Group, a private research firm. The monitor tracks nationwide investment across a number of sectors that make up the new electricity economy, including critical mineral refining, battery manufacturing, solar and wind installation, and electric vehicle and heat pump purchases by consumers (among other variables).
Outside of a promising headline number, the story is a mixed one. Investment in America’s clean manufacturing sector started growing again last quarter after falling for 18 months; it remains about 24% below where it was a year earlier, according to the project. The new growth came overwhelmingly from investment in the EV supply chain — defined as “critical minerals, batteries, vehicle assembly, and charging equipment” — driving a staggering 88% of all clean manufacturing investment. That subsector alone made up more than 9% of all U.S. clean investment.
The more interesting story — and what leaps out from the chart — is that retail activity drove the spring resurgence. High gasoline prices helped here, pushing consumers to buy all-electric and plug-in hybrid vehicles in larger numbers. (Rivian, Tesla, and other automakers started to see an EV rebound last quarter, too, after Republicans ended EV incentives in 2025.) But the real boom came in residential batteries, which surged to an all-time high of $11 billion in quarterly sales. Consumer activity hasn’t made up such a large share of national clean investment since 2023.
This trend wasn’t just happening in the United States. We’ve talked a lot at Heatmap about whether the Strait of Hormuz crisis will drive a clean energy boom. But it's now clear the oil price shock really did encourage global EV adoption. Some 50 countries set new EV sales records in 2026’s second quarter, according to Kelley Blue Book. India, Brazil, and Australia all set record highs. That's a lot of demand destruction.