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Local governments once fought the adoption of wireless communications technology. Then Congress did something.
The landmark Inflation Reduction Act invested some $370 billion toward transitioning the United States to a clean energy economy. Yet turning that spending into actual new energy facilities – getting turbines in the air, and solar arrays on the ground – is another matter.
How many facilities materialize, and how quickly, will hinge on countless permitting processes carried out in cities and towns around the country. And at the hyper-local level, renewable energy developers often meet resistance and drawn-out processes.
If left unchecked, NIMBYism could effectively veto much of the IRA, one project at a time. But fortunately, Congress has a ready-made model to defend their investment: a Clinton-era law that helped bring cellphones to more Americans by partially insulating wireless infrastructure from local resistance. We can do the same thing to ensure that the renewable energy transition is not stonewalled on the ground.
Back in the 1990s, NIMBY opposition was hampering the adoption of then-novel wireless communications technology. Local zoning boards frequently enacted moratoria on new wireless towers, and opponents spread unsubstantiated myths about health risks and complained that the towers were eyesores. This often prevented (or at least delayed) the construction of new towers, which slowed the deployment of cellphone technology. For example, in Georgia, a county commissioner said, “By and large, the towers are ugly, and people don’t want them in their backyards. If folks would stay off their cell phones there would be no need for the towers.” Medina, Washington was one of many cities that enacted multiple moratoria on new cell tower citing; a leading opponent of the cell towers there said, “People are willing to not use their cell phones for three blocks on their way to the grocery store, if that means not having the towers here.”
Rather than let NIMBYism hold back progress, Congress took action. The Telecommunications Act of 1996 passed with overwhelming bipartisan support to “encourage the rapid deployment of new telecommunications technology.” The TCA struck a balance on local permitting and siting: it preserved “the traditional authority of state and local governments to regulate the location, construction, and modification” of wireless towers, but crafted limits on that authority. Under the TCA, local governments can no longer impose regulations tantamount to bans on cell towers. They must issue decisions on proposed towers within a reasonable time, and must support those decisions with “substantial evidence” – in writing. And they cannot turn away projects on the basis of debunked health fears. If a town violates these rules, telecom companies can get an expedited hearing in court.
Congress aimed to let local communities continue to have some say over cell tower siting, but added guardrails to ensure that they couldn’t undermine national imperatives. As Republican Congressman Thomas Bliley, chair of the House Committee on Energy and Commerce, put it at the time: “Nothing is in this bill that prevents a locality … from determining where a cellular pole should be located, but we do want to make sure that this technology is available across the country, that we do not allow a community to say we are not going to have any cellular pole in our locality.”
The TCA paved the way for greater adoption of modern telecommunications technology. Before the law, there were roughly 20,000 wireless towers in the United States and 30 million cellphone users. Six years later, there were nearly 130,000 towers and 130 million users. The TCA continues to reap dividends, such as by neutralizing some of the resistance to the 5G rollout. In 2018, the Federal Communications Commission adopted rules under the TCA to limit the power of localities to obstruct new 5G facilities, constraining the power of cities and towns to block the new sites.
Just as the TCA’s siting rules have helped support the expansion of cellphone networks in the United States, a similar policy could support the expansion of renewable energy. Local permitting has increasingly become a bottleneck for our clean-energy transition. As the Idaho Capital Sun recently observed: “Across the country — from suburban Virginia, rural Michigan, southern Tennessee and the sugar cane fields of Louisiana to the coasts of Maine and New Jersey and the deserts of Nevada — new renewable energy development has drawn heated opposition that has birthed, in many cases, bans, moratoriums and other restrictions[,]” with new wind and solar developments “igniting fierce battles over property rights, loss of farmland, climate change, aesthetics, the merits of renewable power and a host of other concerns.”
A report last year from Columbia University's Sabin Center on Climate Change Law identified 121 local policies restricting renewables development across 31 states, and more than 200 renewables projects challenged across the country – and those numbers are undercounts, according to the Center’s Matthew Eisenson. Common local tactics, the report found, “include moratoria on wind or solar energy development; outright bans on wind or solar energy development; regulations that are so restrictive that they can act as de facto bans on wind or solar energy development; and zoning amendments that are designed to block a specific proposed project.” These local restrictions have been fueled in part by misinformation spread on social media promoting unsupported health and safety concerns around wind and solar farms. Sometimes these groups are literally bankrolled by the oil industry trying to curb the transition from fossil fuels.
Congress could step in to limit localities’ power to obstruct clean energy. Patricia Salkin and Ashira Pelman Ostrow, legal scholars at Albany Law School and Hofstra University, proposed a new legal framework modeled off of the TCA that would outlaw bans and indefinite moratoria on new wind farms, require reasonably fast decisions that are issued in writing and backed by substantial evidence, and create a judicial right of action for wind developers to challenge permitting denials. This would speed up the siting process, and force localities to keep their doors open to renewable energy. And it would incentivize more localities to grant wind citing requests by imposing litigation risk on decisions denying projects.
This framework could provide the foundation for a new Renewable Energy Siting Act – one that, unlike some other permitting reform proposals, would streamline the process for approving renewables only, without sacrificing community protections against fossil fuels. It could also be strengthened. For one, it should apply to other forms of clean energy beyond wind, including solar. The timeline for issuing a decision on a project could be specified at a fixed deadline, like 90 days.
The “substantial evidence” standard could also be bolstered to exclude common NIMBY complaints. In a 2015 Supreme Court case involving the TCA, at least one Supreme Court justice – Justice Alito – said that a permitting decision rejecting a cell tower based solely on aesthetics or community compatibility would count as “substantial evidence.” In adapting the TCA model for renewable energy, Congress should require permitting decisions to be supported by evidence that is both substantial and credible. As it did for fears over radiofrequency emissions from cell towers, Congress could explicitly rule out certain disproven or baseless objections around health, safety, and aesthetics.
Congress could also crack down on extreme and prohibitive “setbacks” – the distance that a structure must be from any neighboring properties – that some states and municipalities impose on renewable facilities. In Ohio, wind turbines must be built at least 1,125 feet from the nearest property line. (Meanwhile, the state allows new oil and gas wells just 100 feet from homes.) That has made new wind development in the state a practical impossibility. Congress could let states and localities take reasonable precautions to protect nearby properties (in the unlikely event that a turbine falls over), while setting a maximum setback rule at perhaps 1.5 times the turbine’s height – a setback of around 450 feet for a typical utility-scale tower.
By design, this approach protects national goals while preserving a role for state and local governments. Though given the climate stakes and the federal dollars at risk, some might understandably want to hand more permitting authority to national agencies. But that risks provoking a backlash, and may also lead federal authorities to miss legitimate local concerns. Putting the federal government in charge of permitting and siting decisions could also trigger federal environmental review under the National Environmental Policy Act and other laws, further slowing deployment.
Though without a new law from Congress reining in local permitting, the Biden administration may have little choice but to resort to targeting specific projects to speed them up. Existing authority under the Defense Production Act allows the federal government to override other laws – including permitting laws – to expedite renewable energy development. The administration has also reportedly started leveraging certain grants to reward states and localities that agree to streamline permitting for projects receiving federal funding. Similar conditions could be attached to some Inflation Reduction Act funding too.
With the House under Republican control, the odds of congressional action seem admittedly slim. But red states and conservative districts stand to benefit mightily from IRA spending given the geographic skew of wind and solar energy toward rural areas in the middle of the country. And providing more national uniformity in permitting processes is fundamentally a pro-business, deregulatory act that will provide more certainty to energy developers. Perhaps those dynamics can produce a bipartisan coalition for congressional action like the one that enacted the TCA.
As we build our way out of the climate crisis, local communities deserve a say in how and where we build, but not a veto. With the climate clock ticking, we can ill afford to run out that clock with undue delays and frivolous objections. Congress can strike the right balance here, and help clean energy proliferate just as quickly as cellphones did.
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The assembly line is the company’s signature innovation. Now it’s trying to one-up itself with the Universal EV Production System.
In 2027, Ford says, it will deliver a $30,000 mid-size all-electric truck. That alone would be a breakthrough in a segment where EVs have struggled against high costs and lagging interest from buyers.
But the company’s big announcement on Monday isn’t (just) about the truck. The promised pickup is part of Ford’s big plan that it has pegged as a “Model T moment” for electric vehicles. The Detroit giant says it is about to reimagine the entire way it builds EVs to cut costs, turn around its struggling EV division, and truly compete with the likes of Tesla.
What lies beneath the new affordable truck — which will revive the retro name Ford Ranchero, if rumors are true — is a new setup called the Ford Universal EV Platform. When car companies talk about a platform, they mean the automotive guts that can be shared between various models, a strategy that cuts costs compared to building everything from scratch for each vehicle. Tesla’s Model 3 and Model Y ride on the same platform, the latter being essentially a taller version of the former. Ford’s rival, General Motors, created the Ultium platform that has allowed it to build better and more affordable EVs like the Chevy Equinox and the upcoming revival of the Bolt. In Ford’s case, it says a truck, a van, a three-row SUV, and a small crossover can share the modular platform.
At the heart of the company’s plan, however, is a new manufacturing approach. The innovation of the original Model T was about the factory, after all — using the assembly line to cut production costs and lower the price of the car. For this “Model T moment,” the company has proposed a sea change in the way it builds EVs called the Ford Universal EV Production System. It will demonstrate the strategy with a $2 billion upgrade to the Ford factory in Louisville, Kentucky, that will build the new pickup.
In brief, Ford has embraced the more minimalist, software-driven version of car design embraced by EV-only companies like Tesla and Rivian. The vehicles themselves are mechanically simpler, with fewer buttons and parts, and more functions are controlled by software through touchscreen interfaces. Building cars this way cuts costs because you need far fewer bits, bobs, fasteners, and workstations in the factory. It also reduces the amount of wiring in the vehicle — by more than a kilometer of the stuff compared to the Mustang Mach-E, Ford’s current most popular EV, the company said.
Ford is in dire need of an electric turnaround. The company got into the EV race earlier than legacy car companies like Toyota and Subaru, which settled on more of a wait-and-see approach. Its Mustang Mach-E crossover has been one of the more successful non-Tesla EVs of the early 2020s; the F-150 Lightning proved that the full-size pickup truck that dominates American car sales could go electric, too.
But both vehicles were expensive to make, and the Lightning struggled to make a dent in the truck market, in part because the huge battery needed to power such a big vehicle gave it a bloated price. When Tesla started a price war in the EV market a few years ago, Ford began hemorrhaging billions from its electric division, struggling to adapt to the new world even as carmakers like GM and Hyundai/Kia found their footing.
The big Detroit brand has been looking for an answer ever since, and Monday’s announcement is the most promising proposal it has put forward. Part of the production scheme is for Ford to build its own line of next-gen lithium-ion phosphate, or LFP batteries in Michigan, using technology licensed from the Chinese giant CATL. Another step is to employ the “assembly tree,” which splits the traditional assembly line into three parallel operations, which Ford says reduces the number of required workstations and cuts assembly time by 15%.
Affordability has always been a bugaboo for the American EV industry, a worry exacerbated by the upcoming demise of the $7,500 tax credit. And while Ford’s manufacturing overhaul will go a long way toward building a light-duty pickup EV that sells for $30,000, so too will a fundamental change in thinking about batteries, weight, and range. The F-150 Lightning isn’t the only pickup with a big battery and an even bigger price. That truck’s power pack comes in at 98 kilowatt-hours; large EV pickups like the Rivian R1T and Chevy Silverado EV have 150 or even 200 kilowatt-hour batteries, necessary to store enough power to give these heavy beasts a decent driving range.
InsideEVs reports, however, that the affordable Ford truck may have a battery capacity of just over 50 kilowatt-hours, which would dramatically reduce its cost to make. The trade-off, then, is range. The Slate small pickup truck that made waves this year for its promised price in the $20,000s would have just 150 miles of range in its cheapest form. Ford hasn’t released any specs for its small EV truck, but even using state-of-the-art LFP chemistry, such a small battery surely won’t deliver many more miles per charge.
Whatever the final product looks like, the new Ford truck and the infrastructure behind it are another reminder that, no matter the headwinds caused by the Trump administration, EVs are the future. Ford had been humming along through its EV struggles because its gas-burning cars remained so popular in America, and so profitable. But those profits collapsed in the first half of 2025, according to The New York Times. Meanwhile, Ford and every other carmaker are struggling to catch up to the Chinese companies selling a plethora of cheap EVs all over the world. Their very future depends on innovating ways to build EVs for less.
Governors, legislators, and regulators are all mustering to help push clean energy past the starting line in time to meet Republicans’ new deadlines.
Trump’s One Big Beautiful Bill Act put new expiration dates on clean energy tax credits for business and consumers, raising the cost of climate action. Now some states are rushing to accelerate renewable energy projects and get as many underway as possible before the new deadlines take effect.
The new law requires wind and solar developers to start construction by the end of this year in order to claim the full investment or production tax credits under the rules established by the Inflation Reduction Act. They’ll then have at least four years to get their project online.
Those that miss the end-of-year deadline will have another six months, until July 4, 2026, to start construction, but will have to meet complicated sourcing restrictions on materials from China. Any projects that get off the ground after that date will face a severely abbreviated schedule — they’ll have to be completed by the end of 2027 to qualify, an all-but-impossibly short construction timeline.
Adding even more urgency to the time crunch, President Trump has directed the Treasury Department to revise the rules that define what it means to “start construction.” Historically, a developer could start construction simply by purchasing key pieces of equipment. But Trump’s order called for “preventing the artificial acceleration or manipulation of eligibility and by restricting the use of broad safe harbors unless a substantial portion of a subject facility has been built,” an ominous sign for those racing to meet already accelerated deadlines.
While the changes won’t suppress adoption of these technologies entirely, they will slow deployment and make renewable energy more expensive than it otherwise would have been. Some states that have clean energy goals are trying to lock in as much subsidized generation as they can to lessen the blow.
There are two ways states can meet the moment, Justin Backal Balik, the state program director at the nonprofit Evergreen Action, told me. Right now, many are trying to address the immediate crisis by helping to usher shovel-ready projects through regulatory processes. But states should also be thinking about how to make projects more economical after the tax credits expire, Balik said. “States can play a role in tilting the scale slightly back in the direction of some of the projects being financially viable,” he said, “even understanding that they’re not going to be able to make up all of the lost ground the incentives provided.”
In the first category, Colorado Governor Jared Polis sent a letter last week to utilities and independent power producers in the state committing to use “all of the Colorado State Government to prioritize deployment of clean energy projects.”
“Getting this right is of critical importance to Colorado ratepayers,” Polis wrote. The nonprofit research group Energy Innovation estimates that household energy expenses in Colorado could be $170 higher in 2030 than they would have been because of OBBB, and $310 higher in 2035. “The goal is to integrate maximal clean energy by securing as much cost-effective electric generation under construction or placed in service as soon as possible, along with any necessary electricity balancing resources and supporting infrastructure,” Polis continued.
As for how he plans to do that, he said the state would work to “eliminate administrative barriers and bottlenecks” for renewable energy, promising faster state reviews for permits. It will also “facilitate the pre-purchase of project equipment,” since purchasing equipment is one of the key steps developers can take to meet the tax credit deadlines.
Other states are looking to quickly secure new contracts for renewable energy. In mid-July, two weeks after the reconciliation bill became law, utility regulators in Maine moved to rapidly procure nearly 1,600 gigawatt-hours of wind and solar — for context, that’s about 13% of the total energy the state currently generates. They gave developers just two weeks to submit proposals, and will prioritize projects sited on agricultural land that has been contaminated with per- and polyfluoroalkyl substances, the chemicals known as PFAS. (When asked how many applications had been submitted, the Maine Public Utilities Commission said it doesn't share that information prior to project selection.)
Connecticut’s Department of Energy and Environmental Protection is eyeing a similar move. During a public webinar in late July, the agency said it was considering an accelerated procurement of zero-carbon resources “before the tax increase takes effect.” The office put out a request for information to renewable energy developers the next day to see if there were any projects ready to go that would qualify for the tax credits. Officials also encouraged developers to contact the agency’s concierge permit assistance services if they are worried about getting their permits on time for tax credit eligibility. Katie Dykes, the agency’s commissioner, said during the presentation that the concierge will engage with permit staff to make sure there aren’t incomplete or missing documents and to “ensure smooth and efficient review of projects.”
New York’s energy office is planning to do another round of procurement in September, the outlet New York Focus has reported, although the solicitation is late — it had originally been scheduled for June. The state has more than two dozen projects in the pipeline that are permitted but haven’t yet started construction, according to Focus, and some of them are waiting to secure contracts with the state.
Others are simply held up by the web of approvals New York requires, but better coordination between New York agencies may be in the works. “I assembled my team immediately and we are trying to do everything we can to expedite those [renewable energy projects] that are already in the pipeline to get those the approvals they need to move ahead,” Governor Kathy Hochul said during a rally at the State University of New York’s Niagara campus last week. The state’s energy research and development agency has formed a team “to help commercial projects quickly troubleshoot and advance towards construction,” according to the nonprofit Evergreen Action. (The agency did not respond to a request for more information about the effort.)
States and local governments are also planning to ramp up marketing of the consumer-based credits that are set to expire. Colorado, for example, launched a new “Energy Savings Navigator” tool to help residents identify all of the rebate, tax credit, and energy bill assistance programs they may be eligible for.
Consumers have even less time to act than wind and solar developers. Discounts for new, used, and leased electric vehicles will end in less than two months, on September 30. Homeowners must install solar panels, batteries, heat pumps, and any other clean energy or efficiency upgrades before the end of this year to qualify for tax credits.
Many states offer additional incentives for these technologies, and some are re-tooling their programs to stretch the funding. Connecticut saw a rush of demand for its electric vehicle rebate program, CHEAPR, after the OBBB passed. Officials decided to slash the subsidy from $1,500 to $500 as of August 1, and will re-assess the program in the fall. “The budget that we have for the CHEAPR program is finite,” Dykes said during the July webinar. “We are trying to be good stewards of those dollars in light of the extraordinary demand for EVs, so that after October 1 we have the best chance to be able to provide an enhanced rebate, to lessen the significant drop in the total level of incentives that are available for electric vehicles.”
As far as trying to address the longer-term challenges for renewables, Balik highlighted Pennsylvania Governor Josh Shapiro’s proposal to streamline energy siting decisions by passing them through a new state board. “One of the big things states can do is siting reform because local opposition and lawsuits that drag forever are a big drag on costs,” Balik told me.
A bill that would create a Reliable Energy Siting and Electric Transition Board, or RESET Board, is currently in the Pennsylvania legislature. (New York State took similar steps to establish a renewable siting office to speed up deployment in 2020, though so far it’s still taking an average of three years to permit projects, down from four to five years prior to the office’s establishment.) Connecticut officials also discussed looking at ways to reduce the “soft costs” of permitting and environmental reviews during the July webinar.
Balik added that state green banks can also play a role in helping projects secure more favorable financing. Their capacity to do so will be significantly higher if the courts force the federal government to administer the Greenhouse Gas Reduction Fund.
When it comes to speeding up renewable energy deployment, there’s at least one big obstacle that governors have little control over. Wind and solar projects need approval from regional transmission operators, the independent bodies that oversee the transmission and distribution of power, to connect to the grid — a notoriously slow process. The lag is especially long in the PJM Interconnection, which governs the grid for 13 mid-Atlantic States, and has generally favored natural gas over renewables. But governors are starting to turn up the pressure on PJM to do better. In mid July, Shapiro and nine other governors demanded PJM give states more of a say in the process by allowing them to propose candidates for two of PJM’s board seats.
“Can we use this moment of crisis to really impress the urgency of getting some of these other things done — like siting reforms, like interconnection queue fixes, that are all part of the economics of projects,” Balik asked. These steps may help, but lengthy federal permitting processes remain a hurdle. While permitting reform is a major bipartisan priority in Congress, as my colleague Matthew Zeitlin wrote recently, a deal that’s good for renewables might require an about-face from the president on wind and solar.
The Danish government is stepping in after U.S. policy shifts left the company’s New York offshore wind project in need of fresh funds.
Orsted is going to investors — including the Danish government — for money it can’t get for its wind projects, especially in the troubled U.S. offshore wind market.
The Danish developer, which is majority owned by the Danish government, told investors on Monday that it would seek to raise over $9 billion, about half its valuation before the announcement, by selling shares in the company.
Publicly traded companies do not typically raise money by selling stock, which is more expensive for the company, tending instead to finance specific projects or borrow money.
But the offshore wind business is not any industry.
In normal times, Orsted and other wind developers will conduct “farm-downs,” selling stakes in projects in order to help finance the next ones. Due to “recent material adverse development in the U.S. offshore wind market,” however, the early-morning announcement said, “it is not possible for the company to complete the planned partial divestment and associated non-recourse project financing of its Sunrise Wind offshore wind project on the terms which would provide the required strengthening of Orsted’s capital structure” — a long way of explaining that it can’t find a buyer at an acceptable price. Hence the new equity.
While the market had been expecting Orsted to raise capital in some form, the scale of the raise is about twice what was anticipated, according to Bloomberg’s Javier Blas.
About two-thirds of the stock sale will be used to continue financing Sunrise Wind, a 924-megawatt planned offshore wind project off the coast of Long Island, according to Morgan Stanley analysts. Construction began last summer, just days after Orsted took full ownership of the project by buying out a stake held by the utility Eversource.
Despite all the sound and fury around offshore wind in the United States, the company said in its earnings report, also released Monday, that “we successfully installed the first foundations at Sunrise Wind, following completion of the wind turbine foundation installation at Revolution Wind,” a 704-megawatt project off the coasts of Rhode Island and Connecticut. “Construction of our offshore U.S. assets is progressing as expected and according to plan,” the company said.
But the report also said Orsted took a hit of over a billion Danish kroner in the first half of this year due to tariffs and what it gingerly refers to as “other regulatory changes, particularly affecting the U.S.,” a.k.a. President Donald Trump.
The president and his appointees have been on a regulatory and financial campaign against the wind sector, especially offshore wind, attempting to halt work on another in-construction New York project, Empire Wind, before Governor Kathy Hochul was able to reach a deal to continue. All future lease sales for new offshore wind areas have been canceled.
Even before Trump came back into office, the offshore wind industry in the U.S. had been hammered by high interest rates, which raised the cost of borrowed money necessary to fund projects, and spiraling supply chain costs and project delays, which also increased the need for the more expensive financing.
“Because of the sharp rise in construction costs and interest rates since 2021, all the projects turned out to be value-destructive,” Morningstar analyst Tancrede Fulop wrote in a note about the Orsted share issue. The company took large losses on scuttled projects in the U.S. and already cancelled its dividend and announced a plan to partially divest many other projects in order to shore up its balance sheet and fund future projects.
While the start-and-stop Empire Wind project belongs to Equinor, Orsted’s Scandinavian neighbor (majority-owned by the Norwegian government), Orsted management told analysts on its conference call that “the issues surrounding Empire Wind's stop-work order from April 2025 had negatively impacted financing conditions for Sunrise,” according to Jefferies analyst Ahmed Furman.
Equinor, too, has had to take a bigger share of Empire Wind, buying out the stake held by BP in January of this year. BP had bought 50% stakes in three Equinor wind projects in 2020, but last year wrote down its investment in the offshore wind sector in the U.S. by over $1 billion.
Why could Orsted not simply pull out of Sunrise Wind? “Orsted and our industry are in an extraordinary situation with the adverse market development in the U.S. on top of the past years’ macroeconomic and supply chain challenges,” Rasmus Errboe, who took over as the company’s chief executive earlier this year, said in a statement. “To deliver on our business plan and commitments in this environment, we’ve concluded that a rights issue is the best solution for Orsted and our shareholders.”
The Danish government will maintain its 50.1% stake in the company, putting the small Scandinavian country with its low-boiling trade and territorial conflicts against the Trump administration in direct capitalist conflict with the American president and his least favorite form of electricity generation.
In the immediate wake of the announcement, Jefferies analyst Ahmed Farman wrote to clients that the deal would “obviously de-risk the [balance sheet], but near-term dilution risk seems substantial,” citing the unexpected magnitude of the raise and no sign pointing to new growth. “As a result, we expect the initial stock reaction to be quite negative.”
And so it has been: The stock closed down almost 30%, its biggest-ever single-day drop and below the price at which it went public in 2016, according to Bloomberg data.