You’re out of free articles.
Log in
To continue reading, log in to your account.
Create a Free Account
To unlock more free articles, please create a free account.
Sign In or Create an Account.
By continuing, you agree to the Terms of Service and acknowledge our Privacy Policy
Welcome to Heatmap
Thank you for registering with Heatmap. Climate change is one of the greatest challenges of our lives, a force reshaping our economy, our politics, and our culture. We hope to be your trusted, friendly, and insightful guide to that transformation. Please enjoy your free articles. You can check your profile here .
subscribe to get Unlimited access
Offer for a Heatmap News Unlimited Access subscription; please note that your subscription will renew automatically unless you cancel prior to renewal. Cancellation takes effect at the end of your current billing period. We will let you know in advance of any price changes. Taxes may apply. Offer terms are subject to change.
Subscribe to get unlimited Access
Hey, you are out of free articles but you are only a few clicks away from full access. Subscribe below and take advantage of our introductory offer.
subscribe to get Unlimited access
Offer for a Heatmap News Unlimited Access subscription; please note that your subscription will renew automatically unless you cancel prior to renewal. Cancellation takes effect at the end of your current billing period. We will let you know in advance of any price changes. Taxes may apply. Offer terms are subject to change.
Create Your Account
Please Enter Your Password
Forgot your password?
Please enter the email address you use for your account so we can send you a link to reset your password:
Five findings from an extremely thorough study by the National Renewable Energy Lab.

Some Americans install heat pumps because they care about climate change. But most people aren’t going to make the switch until it makes sense economically. Pinpointing where and for whom heat pumps are a good investment is surprisingly tricky because U.S. housing is so diverse, with a wide range of building sizes and ages, situated in different local climates with different utility rates.
But for the first time, researchers at the National Renewable Energy Lab have sorted through much of this complexity to get deeper to the truth about the costs, benefits, and challenges of deploying heat pumps in the U.S.
Ultimately, they found that heat pumps are a cost-effective choice in roughly 65 million U.S. homes, or about 60% of the country — and that’s before taking into account available subsidies. But there are substantial economic barriers to widespread adoption.
It’s hard to overstate how detailed the study is. The authors started with a model of 550,000 statistically representative households — basically housing archetypes that typify different combinations of building size, age, occupancy level, local climate, heating usage patterns, and existing heating systems. Each one represents about 242 real-world households. Then the authors looked at how switching to a heat pump would affect greenhouse gas emissions and energy bills across all of these different homes in a wide range of scenarios. They considered heat pumps with lower and higher efficiency ratings, and whether or not the building owner pursued insulation upgrades. They looked at different scenarios for how quickly the grid would decarbonize, how sensitive the results were to energy prices, and how subsidies from the Inflation Reduction Act affect the economics.
The paper has many interesting findings beyond the top-line result. Here are five things that stood out.
Eric Wilson, a senior research engineer at NREL and the study’s lead author, told me one of his motivations was to try to settle the question of whether heat pumps reduce emissions.
“I see a lot of people saying, well, the grid is still dirty in this state, and maybe it makes sense to wait five years to put in a heat pump because it could increase emissions,” he said.
But he found that in each of the 48 contiguous U.S. states, switching to a heat pump reduces emissions today, even if that heat pump is one of the cheaper, less-efficient models. Heat pumps are just so much more efficient than other options that they still reduce emissions despite today’s relatively dirty grid.
On average, each home could cut between 2.5 to 4.4 tons of carbon over the approximately 16 years the equipment lasts, meaning widespread adoption could result in a 5% to 9% drop in national economy-wide emissions. The effect is much more pronounced in some states, like those in the Northeast, where a lot of homes currently use fossil fuels for heating. A household in Maine that installs a high efficiency model, combined with completing insulation upgrades, would reduce emissions by an average of 11 tons per year — or about the equivalent of taking two cars off the road for a year.
The study breaks down the costs of switching to a heat pump in a few different ways.
First, there’s the up-front costs of upgrading to a heat pump, which are relatively high. A lower-rated, less efficient heat pump system may be a cheaper option than a new furnace or boiler for about 43% of households. But a higher-performing heat pump is almost always more expensive, costing an extra $8,000 to $13,000 before government subsidies (more on them later). That alone might keep heat pumps out of reach for many households.
Next, there's the potential for bill savings — which is significant. Using state average electricity and gas rates in the winter of 2021 to 2022, the study found that 86% of households can save money on their utility bills by switching to a medium-efficiency heat pump, and a whopping 95% of households will see their bills go down if they install the highest efficiency system.
So in theory, if homeowners do have the extra cash to put down, there’s a chance they could make up for high up-front costs in bill savings over time. But how good a chance?
Putting this all together, the authors looked at what percentage of households that upgraded to heat pumps would see a positive cash flow, calculated as the “net present value,” from the initial investment. Here, the results were less rosy. In many cases, high up-front costs cancel out potential savings. For example, despite the near-certain bill savings from buying one of the most efficient heat pump models, only 21% of households would see an overall economic benefit from the switch.
Still, more than half of all homes would see a positive cash flow by switching to a cheaper, minimum-efficiency heat pump.

These findings underscore the importance of bringing down the cost of more efficient heat pump models, which are out of reach for many Americans but can provide significant energy bill savings. The authors suggest that policymakers can help by deploying incentives more strategically and pursuing research on “lower-cost, higher performance, and easier to install equipment.” There also may be opportunities for bulk purchasing and aggregating installations across an apartment building or neighborhood.
When it comes to bill savings, the study found that those who have systems that run on propane, fuel oil, or electric resistance heaters will pretty much always lower their bills by switching to a heat pump, no matter how efficient it is. But those who use natural gas are far more likely to lower their bills if they can afford to switch to one of the pricier, better-performing heat pumps — which cuts into the value proposition.
The following maps show the percentage of homes in each state that would see a positive cash flow from switching to a heat pump, looking at those switching from natural gas, electric resistance, or fuel oil and propane, illustrating how the value proposition is most challenging for those using natural gas.

The authors also note that fixed charges on natural gas bills can play a significant role in the economics of switching to a heat pump. Most natural gas utilities charge customers a fixed amount each month, regardless of how much gas they use. If a homeowner switches to heat pumps but continues using gas for cooking, they’ll still have to pay the full fee, which can be as high as $34 a month, whereas homes that fully electrify can avoid these fees.
The results I described in the previous two sections include homes both with and without existing air conditioning systems of some kind. (With the exception of the maps, which only consider homes that have air conditioning already.)
But since heat pumps provide both heating and cooling, the economics are actually quite different for those households who already have air conditioners versus those who don't. If a household already has A/C, heat pumps appear more favorable, because a family would be able to replace two systems — an air conditioner and a furnace — with just one. If there is no pre-existing air conditioner, the heat pump will not only have higher up-front costs, but it’s more likely to increase energy bills, since the family might start using the heat pump for cooling in addition to heating.
Here are the same maps included in the previous section, but looking just at homes that do not have air conditioning.

There are basically zero cases where a house with natural gas heating, and no A/C, will save by switching to a heat pump. However, that result doesn’t take into account the benefits of getting air conditioning for the first time.
“They didn't include the new value that someone has, especially in a warming world and a world with more heat waves, of now having an air conditioner in your home,” Kevin Kircher, an assistant professor of mechanical engineering at Purdue University, told me. “So if you add that in, I think the economics look better.”
None of the results in the previous sections take into account the various subsidies that states and the federal government offer for heat pumps. For example, the Inflation Reduction Act included a $2,000 tax credit for heat pumps and an additional $11,500 in rebates for low- and moderate-income households. Both will increase the percentage of households for whom the investment will pencil out.
The study also doesn’t take into account the potential for homes to use smart controls that optimize their systems, or the opportunity for households to participate in demand response programs which will pay them to turn down their thermostats by a few degrees when the grid is taxed. Kircher, the Purdue professor, recently published a study of a real-world house in a cold climate where smart controls reduced heating energy costs by 23-34%.
Finally, one big takeaway from the study was that the results are very sensitive to the price ratio between natural gas rates and electricity rates, and there are reasons to believe that may become more favorable. For example, as more renewable energy is deployed, electricity could become more affordable. Meanwhile, if the U.S. increases exports of liquified natural gas, the cost of domestic natural gas could go up. The study cites a 2022 survey of oil and gas executives which found that 69% expect ‘‘the age of inexpensive U.S. natural gas to end by year-end 2025.”
“Big modeling like this entails a lot of assumptions about the future that are really hard to pin down with any real precision,” said Kircher. “But I think there's cause for optimism there.”
Log in
To continue reading, log in to your account.
Create a Free Account
To unlock more free articles, please create a free account.
Members of the nation’s largest grid couldn’t agree on a recommendation for how to deal with the surge of incoming demand.
The members of PJM Interconnection, the country’s largest electricity market, held an advisory vote Wednesday to help decide how the grid operator should handle the tidal wave of incoming demand from data centers. Twelve proposals were put forward by data center companies, transmission companies, power companies, utilities, state legislators, advocates, PJM’s market monitor, and PJM itself.
None of them passed.
“There was no winner here,” PJM chief executive Manu Asthana told the meeting following the announcement of the vote tallies. There was, however, “a lot of information in these votes,” he added. “We’re going to study them closely.”
The PJM board was always going to make the final decision on what it would submit to federal regulators, and will try to get something to the Federal Energy Regulatory Commission by the end of the year, Asthana said — just before he plans to step down as CEO.
“PJM opened this conversation about the integration of large loads and greatly appreciates our stakeholders for their contributions to this effort. The stakeholder process produced many thoughtful proposals, some of which were introduced late in the process and require additional development,” a PJM spokesperson said in a statement. “This vote is advisory to PJM’s independent Board. The Board can and does expect to act on large load additions to the system and will make its decision known in the next few weeks.”
The surge in data center development — actual and planned — has thrown the 13-state PJM Interconnection into a crisis, with utility bills rising across the network due to the billions of dollars in payments required to cover the additional costs.
Those rising bills have led to cries of frustration from across the PJM member states — and from inside the house.
“The current supply of capacity in PJM is not adequate to meet the demand from large data center loads and will not be adequate in the foreseeable future,” PJM’s independent market monitor wrote in a memo earlier this month. “Customers are already bearing billions of dollars in higher costs as a direct result of existing and forecast data center load,” it said in a quarterly report released just a few days letter, pegging the added charges to ensure that generators will be available in times of grid stress due to data center development at over $16 billion.
PJM’s initial proposal to deal with the data center swell would have created a category for new large sources of demand on the system to interconnect without the backing of capacity; in return, they’d agree to have their power supply curtailed when demand got too high. The proposal provoked outrage from just about everyone involved in PJM, including data center developers and analysts who were open to flexibility in general, who said that the grid operator was overstepping its responsibilities.
PJM’s subsequent proposal would allow for voluntary participation in a curtailment program, but was lambasted by environmental groups like Evergreen Collaborative for not having “any semblance of ambition.” PJM’s own market monitor said that voluntary schemes to curtail power “are not equivalent to new generation,” and that instead data centers should “be required to bring their own new generation” — essentially to match their own demand with new supply.
A coalition of environmental groups, including the Natural Resources Defence Council and state legislators in PJM, said in their proposal that data centers should be required to bring their own capacity — crucially counting demand response (being paid to curtail power) as a source of capacity.
“The growth of data centers is colliding with the reality of the power grid,” Tom Rutigliano, who works on grid issues for the Natural Resources Defense Council, said in a statement. “PJM members weren’t able to see past their commercial interests and solve a critical reliability threat. Now the board will need to stand up and make some hard decisions.”
Those decisions will come without any consensus from members about what to do next.
“Just because none of these passed doesn’t mean that the board will not act,” David Mills, the chairman of PJM’s board of managers, said at the conclusion of the meeting. “We will make our best efforts to put something together that will address the issues.”
California energy companies are asking for permission to take in more revenue. Consumer advocates are having none of it.
There’s a seemingly obvious solution to expensive electricity bills: Cut utility profits.
Investor-owned utilities have to deliver profits to their shareholders to be able to raise capital for grid projects. That profit comes in the form of a markup you and I pay on our electricity bills. State regulators decide how much that mark-up is. What if they made it lower?
A growing body of evidence suggests they should at least consider it. In principle, the rate of return on equity, or ROE, that regulators allow utilities to charge should reflect the risk that equity investors are taking by putting their money in those utilities, but that relationship seems to have gotten out of whack. Among the first to draw attention to the issue was a 2019 paper by Carnegie Mellon researchers which found that since the 1990s, the average “risk premium” exhibited by utility ROEs as compared to relatively risk-free U.S. Treasury bonds has grown from 3% to nearly 8%.
“An error or bias of merely one percentage point in the allowed return would imply tens of billions of dollars in additional cost for ratepayers in the form of higher retail power prices,” the authors wrote.
Subsequent research reproduced and built on those findings, showing that a generous ROE creates a perverse incentive for utilities to increase their capital investments, leading to excess costs for consumers of $3 billion to $11 billion per year. Now, the ex-chief economist of a major U.S. utility company, Mark Ellis, is putting his own analysis out there, arguing that unreasonably high ROEs are costing U.S. energy customers $50 billion per year, or over $300 per household.
Not only does this hurt consumers, it also makes the energy transition more expensive and less politically palatable.
That’s what environmental and consumer advocates are worried about in California, where the Public Utility Commission is currently considering requests by the state’s four largest energy companies to raise each of their ROE. Utilities in the state have reported record profits amid a worsening affordability crisis. On Friday, the commission signaled that it would instead lower the companies’ ROE — although not nearly as much as advocates have recommended. A final decision is expected in December.
“It’s a joke,” Ellis, the former utility executive, told me of the commission proceedings. “If you read the proposed decision, they don’t address any of the facts or evidence in the case at all.” His own analysis, which he submitted to the California commission on behalf of the Sierra Club, proposes that an average ROE of 6%, down from about 10%, would be justified and has the potential to save California energy customers more than $6 billion per year.
Utilities, of course, disagree, and have brought their own analysis and warnings about the risks of lowering their ROE. Regulators are left to sort through it all to figure out the magic number — one large enough to appeal to investors, but not so large as to throw ratepayers under the bus.
How does the ROE work its way into your bill? Let’s say your local utility, The Electric Company, has a regulated return on equity of 10%, and it plans to spend $100 million to build new substations. Utilities typically finance these kinds of capital projects with a mix of debt (loans they will have to pay interest on) and equity (shares sold to investors). Then they recover that money from ratepayers over the course of decades. If The Electric Company raises half of the capital, or $50 million, via equity, an ROE of 10% means it will be able to charge ratepayers $5 million on top of the cost of the project. That additional $5 million is factored into the per-killowatt-hour rates that customers pay. The profit can then be reinvested into future projects, issued to shareholders as dividends, paid out to executives as bonuses — the list goes on.
The energy research group RMI, which agrees that the average utility ROE is much too high, estimates the surcharge currently makes up between 15% and 20%% of the average customer’s utility bill. “Setting ROEs at the right level is necessary to bring forward a rapid, just, and equitable transition,” RMI wrote.
Utilities, however, say the “right level” is likely higher, not lower. They warn that in reality, lowering their ROE would trigger a cascade of negative effects — credit downgrades, higher borrowing costs, lower stock prices, investors taking their money elsewhere — that would push energy rates up, not down. These effects would also make it more difficult for utilities to invest in projects to clean up and expand the electric grid.
Timothy Winter, the portfolio manager of a utility-focused fund at the investment firm Gabelli, told me this “virtuous cycle” runs in both directions. Higher ROEs lead to a lower cost of capital, which leads to more investment, better reliability, and lower rates, he argued. Winter said that if California regulators reduced utility ROEs to 6%, investors would flee the state.
Between growing wildfire risk and the bankruptcy of California’s largest utility, PG&E, California energy providers are too exposed to warrant such low returns, he said. As a comparison, he noted that U.S. Treasury bonds, which are generally viewed as risk-free, yield about 4%. “If it’s a 6% return with an equity risk, they’re not going to do it,” he said of investors.
I probed Winter a bit more on this. Is that really true given that utilities are still, in many ways, the opposite of risky investments? They have captive customers, stable income, and are seeing skyrocketing growth in demand for their product.
This caused him to spiral down into an investor’s worst nightmare scenario. “Yes, there is a risk,” he said. “If a regulator is willing to give a 6% return and they used to give 11%, how do I know they’re not going to decide, okay, rates keep going up, next rate case it’s going to be 4%?” After that, he said, how can investors be sure the government won’t end up taking over the utility altogether?
Travis Miller, a senior equity analyst at Morningstar, was more measured. He hesitated to tell me whether a 6% ROE would hurt utilities’ ability to raise capital. “What usually happens” when regulators lower the ROE, he said, “is the utilities just decide not to invest very much, so then they don’t have to raise capital.” He would expect the California utilities to “invest to maintain reliability and that’s about it,” meaning that “a lot of new data center build that is planned in California would have to go elsewhere.”
Return on equity also isn’t the only thing investors look at, Miller added. They consider the overall regulatory environment. Is it predictable? Is it transparent? He said there have been cases where regulators cut a utility’s ROE but the overall regulatory environment remained strong, and other instances where the cut to ROE was “another sign of a deteriorating relationship” — a phrase that brings to mind Winter’s panic about government takeovers. (I should note, advocates for public takeovers of utilities cite this whole dynamic around the need to woo investors and the perverse incentives it creates as a key justification for their cause. Publicly-owned utilities — which serve about 1 in 7 electricity customers in the U.S., including in large cities like Sacramento, Los Angeles, and Seattle — don’t charge an ROE.)
When I spoke to Ellis about his proposal, I fired off all of the utility arguments I could think of. Won’t utilities stop building stuff and making the investments we need them to make if they can’t earn as much? “They have a legal obligation to continue to invest,” he said. But will they be able to raise equity? They don’t necessarily need to raise new equity, he responded, suggesting that utilities could reinvest more of their profits rather than distributing the money as dividends. This is not how utilities traditionally operate, he admitted, but it’s an option.
Prior to taking up the consumer cause, Ellis spent 15 years in leadership and executive roles at Sempra Energy, the parent company of San Diego Gas and Electric and SoCal Gas — two of the companies that petitioned for higher ROE. “I know how they think about this issue,” he told me, asserting that the arguments the companies make to regulators do not match how they think about ROE internally.
During our interview, Ellis described the current state of utility regulation of ROE in California as “reprehensible,” “egregious,” “heartbreaking,” and “a huge injustice.”
In the analysis he submitted to the utility commission, Ellis not only makes the case that the average U.S. utility’s ROE is much higher than is necessary to attract capital, but also that the potential impacts to consumers of lowering it — i.e. the potential to hurt a utility’s credit rating and increase its cost of debt — would be outweighed by customer savings.
He argues that to justify their requests for higher ROEs, the utilities use forecasts from biased sources, cherry-pick and manipulate data, and make economically impossible assumptions, like that earnings will grow faster than GDP.
Stephen Jarvis, an assistant professor at the London School of Economics who has conducted research on ROE rates, has reached similar conclusions about them being excessively high. Nonetheless, he told me he sympathized with the challenge regulators face. He said there was no “right” answer for how to calculate the appropriate ROE. “Depending on the assumptions that you use, you can come up with quite different numbers for what a fair rate of return should be,” he said.
The sentiment echoes the preliminary decision the California Public Utilities Commission issued last week, when it observed that all of the proposals submitted in the proceeding were “dependent on subjective inputs and assumptions.”
Ellis said the decision contained a “smoking gun,” however, proving that the commission didn’t really do its job. Changes in ROE are supposed to reflect changes to a company’s risk profile, he said. The risk profile for Southern California Edison, which is facing lawsuits related to the Eaton Fire and already paying out hundreds of millions of dollars to survivors, has certainly changed in a different way than its peers. Regardless, the commission made the exact same recommendation for each utility to reduce ROE by 0.35%. “The Commission clearly is not looking at the evidence.”
There is likely some truth to that. “It’s more art than science,” Cliff Rechtschaffen, who served for six years on the California Public Utilities Commission, told me when I asked how the people in those seats attempt to calibrate ROE. He acknowledged there was a self-reinforcing element to the process — regulators look at where investors might go if the rate of return is too low, and use that to determine what the rate should be. “But the rates of return that are set in other jurisdictions are, in turn, influenced by the national utility market, which includes your own utility market,” he said.
Similarly, regulators rely on market analysts, investment advisors, investment bankers, and so on, who have an inherent interest in building up the market and ensuring healthy rates of return, he said. “That makes it harder to discern and do true price discovery.”
Rechtschaffen said he was glad that environmental and consumer advocates were bringing greater scrutiny to ROE, adding that it was the “right time” to do so. “Particularly in this environment where utilities have forecast that they’re going to be spending tens of billions of dollars on capital upgrades, do we need the same rates of return that we’ve seen?”
On ravenous data centers, treasured aluminum trash, and the drilling slump
Current conditions: The West Coast’s parade of storms continues with downpours along the California shoreline, threatening mudslides • Up to 10 inches of rain is headed for the Ozarks • Temperatures climbed beyond 50 degrees Fahrenheit in Greenland this week before beginning a downward slide.
The Department of Energy’s Loan Programs Office just announced a $1 billion loan to finance Microsoft’s restart of the functional Unit 1 reactor at the Three Mile Island nuclear plant. The funding will go to Constellation, the station’s owner, and cover the majority of the estimated $1.6 billion restart cost. If successful, it’ll likely be the nation’s second-ever reactor restart, assuming Holtec International’s revival of the Palisades nuclear plant goes as planned in the next few months. While the Trump administration has rebranded several loans brokered under its predecessor, this marks the first completely new deal sanctioned by the Trump-era LPO, a sign of Energy Secretary Chris Wright’s recent pledge to focus funding on nuclear projects. It’s also the first-ever LPO loan to reach conditional commitment and financial close on the same day.
“Constellation’s restart of a nuclear power plant in Pennsylvania will provide affordable, reliable, and secure energy to Americans across the Mid-Atlantic region,” Wright said in a statement. “It will also help ensure America has the energy it needs to grow its domestic manufacturing base and win the AI race.” Constellation’s stock soared in after-hours trading in response to the news. Holtec’s historic first restart in Michigan got the green light from regulators to come back online in July, as I reported in this newsletter at the time. But already another company is lining up to turn its defunct reactor back on: As I reported here in August, utility giant NextEra wants to revive its Duane Arnold nuclear station in Iowa. The push to restart older reactors reflects a growing need for electricity long before new reactors can come online. Meanwhile, next-generation reactors are plowing ahead. The nuclear startup Valar Atomics claimed this week to achieve criticality long before the July 4 deadline set in an Energy Department competition.
Over the next five years, American demand for electricity is set to grow by the equivalent of 15 times the peak demand of the entirety of New York City. That’s according to the latest annual forecast from the consultancy Grid Strategies. The growth — roughly sixfold what was forecast in 2022 — comes overwhelmingly from data centers, as shown by which regions expect the largest growth:

“The fact that these facilities are city-sized is a huge deal,” John Wilson, Grid Strategies’ vice president and the report’s lead author, told Canary Media. “That has huge implications if these facilities get canceled, or they get built and don’t have long service lives.” Mounting political opposition to data centers could make deals less certain. A Heatmap Pro survey in September found just 44% of Americans would welcome a data center opening nearby. And last week I wrote about how progressives in Congress are rallying around a crackdown on data centers.
Sign up to receive Heatmap AM in your inbox every morning:
The contrast couldn’t be starker. In Washington, President Donald Trump rolled out the red carpet for Saudi Crown Prince Mohammed bin Salman, offering an opulent welcome to the White House and lashing out at reporters who asked about September 11 or the killing of journalist Jamal Khashoggi. In Belém, Brazil, meanwhile, former Vice President Al Gore tore into the team of delegates Saudi Arabia sent to the United Nations climate summit for “flexing its muscles” in negotiations about how to shift away from oil and gas. “Saudi Arabia appears to be determined to veto the effort to solve the climate crisis, only to protect their lavish income from selling the fossil fuels that are the principal cause of the climate crisis,” Gore told the Financial Times. “I hope that the rest of the world will stand up to this obscene greed and recklessness on the part of the kingdom.”
But the Trump meeting could yield some progress on clean energy. Among the top issues the White House listed in its read-out of the summit was the push to export American atomic energy technology to Saudi Arabia as the country looks to follow the United Arab Emirates in embracing nuclear power.
Facing growing needs for domestic sources of metal for the energy transition, the European Union is seeing its trash as treasure. On Tuesday, the European Commission proposed restricting exports of aluminum scrap amid what The Wall Street Journal called “concerns that rising outflows of the resource could leave Europe short of a critical input for its decarbonization efforts.” Speaking at the European Aluminum Summit, EU trade chief Maros Sefcovic referred to the exports as “leakage.” The proposal wouldn’t fully block sales of aluminum scrap overseas, but would adopt a “balanced” measure that ensures sufficient supplies and competitive prices in the single market. “Scrap is a strategic commodity given its important contribution to circularity and decarbonization, as production from secondary materials releases less emissions and is less energy intensive, as well as to our strategic autonomy,” Sefcovic said. The measure is set to be adopted by spring 2026.
In the U.S., the Biden administration made what Heatmap’s Matthew Zeitlin last year called a “big bet” on aluminum. The Trump administration slapped steep new tariffs on imported aluminum, though as our colleague Katie Brigham wrote, “aluminum producers rely on imports of these same materials to build their own plants. Tariffs on these vital construction materials — plus exorbitant levies on all goods from China — will make building new production facilities significantly costlier.”

The average number of active rigs per month that are drilling for oil and natural gas in the continental United States fell steadily over the past year. As of last month, the U.S. had 517 rigs in operation, down from a peak of 750 in the end of 2022. The number of oil-pumping rigs dropped 33% to 397 rigs, while gas-pumping rigs slid 23% to 120 rigs over the same period from December 2022 to October 2025. While the Energy Information Administration said the declining rig count “reflects operators’ responses to declining crude oil and natural gas prices,” the federal research agency said it’s also “improvement in drilling efficiencies,” meaning companies are getting more fuel out of existing wells.
It’s been a pattern in recent research on sustainability. Scientists look at methods that Indigenous groups have maintained as traditions only to find that approaches that have sustained throughout centuries or millennia are finding new value now. A study by the University of Hawaiʻi at Mānoa’s Hawaiʻi Institute of Marine Biology found that Native Hawaiian aquaculture systems — essentially fish ponds known as loko iʻa — effectively shielded fish populations from the negative impacts of climate change, demonstrating resilience and bolstering local food security. “Our study is one of the first in academic literature to compare the temperatures between loko iʻa and the surrounding bay and how these temperature differences may be reflected in potential fish productivity,” lead author Annie Innes-Gold, a recent PhD graduate from the university, said in a press release. “We found that although rising water temperature may lead to declines in fish populations, loko iʻa fish populations were more resilient.”