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A conversation with Resources for the Future’s David Wear on the fires in the Carolinas and how the political environment could affect the future of forecasting.

The Wikipedia article for “wildfire” has 22 photographs, including those of incidents in Arizona, Utah, Washington, and California. But there is not a single picture of a fire in the American Southeast, despite researchers warning that the lower righthand quadrant of the country will face a “perfect storm” of fire conditions over the next 50 years.
In what is perhaps a grim premonition of what is to come, several major fires are burning across the Southeast now — including the nearly 600-acre Melrose Fire in Polk County, North Carolina, a little over 80 miles to the west of Charlotte, and the more than 2,000-acre Carolina Forest fire in Horry County, South Carolina. The region is also battling hundreds of smaller brush fires, the smoke from which David Wear — the land use, forestry, and agriculture program director at Resources for the Future — could see out his Raleigh-area window.
Wear is also the co-author of a study by RFF and the U.S. Forest Service that came out in late 2024 and singled out the Southeast as facing a “particularly worrisome” rise in wildfire risk over the next half-century. I spoke with him this week to learn more about why the Carolinas are burning and what the future of fire looks like for the region. Our conversation has been edited and condensed for clarity.
When discussing fires in the American West, we often talk about how historic suppression efforts are responsible for the megafires we see today. What was the historic fire regime like in the Southeast? What’s going on to make it a hot spot for wildfires?
First, there are the similarities. Both Western and Southeastern forests, especially pine forests, are fire-adapted systems; they need regular fires to maintain health. Anything that takes those forests out of balance is a problem, and fire suppression is an issue in the East and the West, and especially in the Southeast. But forests in the Southeast are the most heavily managed forests in the country — perhaps in the world. In many cases, they’re regularly burned; the South does more prescribed burning than the rest of the country combined. It’s a very, very common practice in this part of the world.
So we shouldn’t be surprised that there is fire in Southeastern forests. There have been big, episodic fires in the South, though they’re not as common. There was the fire in 2016 in East Tennessee, from the Smokies into Gatlinburg, with a number of fatalities and lots of structures damaged or destroyed. There have been big fire years in east and west Texas. And there have been big fire seasons in Florida, though it’s been a while.
How is population growth in the Southeast adding to the strain?
We’re accustomed to talking about the wildland-urban interface in the West, but it’s also a big issue in the Southeast. Some of our urban growth centers in the Southeast include the Raleigh-Durham area, where I live, and Atlanta, Nashville, and Florida. These are generally flat landscapes, as well as very heavily forested landscapes. As the population grows out of the city centers, they go into pine and mixed-pine hardwood forests that are fire-adapted ecosystems. Then you have interspersed communities with forest vegetation, and that’s a big issue.
I also read in your report that much of that land is privately owned, which makes management tricky.
Private ownership is about 89% of forests in the South. [Editor’s note: By comparison, only about a third of forests in the West are privately owned.] Even where you have public ownership, a lot of that is by the Department of Defense and concentrated in a couple of different areas in the Ozarks and southern Appalachians. Much of the landscape in the coastal plain and Piedmont — which is most of the South — is predominantly private ownership.
There’s a distinction to be made between commercial owners, like timber investment management companies or real estate investment trusts, who actively manage landscapes. With timber harvesting, there are a lot of risk mitigation activities and a lot of prescribed burning. But then you have over a million non-industrial private landowners with small holdings. If you’re trying to coordinate any kind of wildfire mitigation scheme using fuel treatments and the like, it requires some work.
Horry County, South Carolina, and Polk County, North Carolina, were not part of your paper’s list of counties vulnerable to wildfire. I’m curious if you think what we’re seeing now says something about the limits of the study and the data you had available, or if you have another takeaway about what’s going on.
Importantly, our study looked at long-term averages. Throughout the South, there is a fire regime, and in any given year, it is possible to have wildfires of consequence. I would point out that we were especially concerned this year because Hurricane Helene laid down an awful lot of trees and created a fuel load.
We’re also entering one of the two fire seasons in the South. Wildfire is most predominant in the spring and in the fall; it’s at those times when temperatures begin to rise but humidity remains low, and there are extended dry periods that allow the fuels to dry out. You have warm temperatures and wind in the spring, setting the stage for wildfire. Typically, that window will begin to close at the end of April because it’s pretty darn humid in the South at that point, and it’s much less likely that fuels will get dry enough to carry a fire.
The same thing happens in the fall: Temperatures may remain high, and if we don’t have a lot of precipitation and humidity — usually in October and into November — then you have the conditions right for fire. But as the climate shifts, we see the length of those seasons growing to the point where the fall is approaching the spring. Wildfires in January and February indicate that these two seasons are growing toward one another and providing a much longer season. Our paper showed that, when you account for climate change across all of those global climate models and representative concentration pathways, the windows for more wildfire activity and more intense wildfire activity are expanding.
Your paper cited wildfire risks across the Sun Belt. Today, the National Weather Service is warning of “potentially historic” fire conditions in central Texas. Can local emergency managers use your modeling to prepare for such situations?
Things like the year-to-year fire projections and the day-to-day forecasts best serve local emergency managers. Wildfire in the South is determined by the drying of fuels and temperature and humidity conditions, which vary daily. If we look over the last week, Saturday was beautiful in the Carolinas. It was sunny, in the 70s, dry, and a little windy. That was the day [hundreds of] fires started across the Southeast. And the next day, there were very few new fires. Mid-week projections of wildfire potential in the Southeast show that it’s really low, with the exception of Texas. It changes day to day, driven by fine-grain weather forecasts, and that gives emergency managers some insight into where they might want to pre-position crews or do pre-suppression activities.
What we’re doing with the modeling is asking, What is this going to look like in 50 years? The takeaway is that wildfire activity is going to remain strong and perhaps grow in the West, but the big structural change is really strong growth and active fire in the Southeast, where you have wildfire and wildlands proximal to millions of people and more vulnerable communities. It’s a fire regime that’s going to affect more people.
I also wanted to ask about the USDA Forest Service’s contributions to your paper. Do you think research like this could still happen today, given the Trump administration’s efforts to eliminate anything climate-related from the federal agenda?
I came to Resources for the Future six years ago after a long career with the Forest Service, so it’s hard for me to remain a dispassionate scientist here. I think we need to see how the dust settles. It’s hard to imagine a future where the agency and federal government do not have a high level of concern regarding fire — and I don’t think you can do any kind of effective planning, or thinking about the future, or targeting of activities without understanding how climate is likely to impact these disturbance regimes.
I don’t have the crystal ball that many people are seeking right now. We’ll have to wait to see. But our research demonstrates the vital role of understanding climate dynamics, and it shows how critical weather forecasts are for people with boots on the ground who are trying to stay ahead of disaster.
Editor’s note: This story has been updated to reflect that about a third of land in the West is privately owned, not publicly owned.
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New Jersey Governor-elect Mikie Sherrill made a rate freeze one of her signature campaign promises, but that’s easier said than done.
So how do you freeze electricity rates, exactly? That’s the question soon to be facing New Jersey Governor-elect Mikie Sherrill, who achieved a resounding victory in this November’s gubernatorial election in part due to her promise to declare a state of emergency and stop New Jersey’s high and rising electricity rates from going up any further.
The answer is that it can be done the easy way, or it can be done the hard way.
What will most likely happen, Abraham Silverman, a Johns Hopkins University scholar who previously served as the New Jersey Board of Public Utilities’ general counsel, told me, is that New Jersey’s four major electric utilities will work with the governor to deliver on her promise, finding ways to shave off spending and show some forbearance.
Indeed, “We stand ready to work with the incoming administration to do our part to keep rates as low as possible in the short term and work on longer-term solutions to add supply,” Ralph LaRossa, the chief executive of PSE&G, one of the major utilities in New Jersey, told analysts on an earnings call held the day before the election.
PSE&G’s retail bills rose 36% this past summer, according to the investment bank Jefferies. As for what working with the administration might look like, “We expect management to offer rate concessions,” Jefferies analyst Paul Zimbrado wrote in a note to clients in the days following the election, meaning essentially that the utility would choose to eat some higher costs. PSE&G might also get “creative,” which could mean things like “extensions of asset recoverable lives, regulatory item amortization acceleration, and other approaches to deliver customer bill savings in the near-term,” i.e. deferring or spreading out costs to minimize their immediate impact. “These would be cash flow negative but [PSE&G] has the cushion to absorb it,” Zimbrado wrote.
In return, Silverman told me that the New Jersey utilities “have a wish list of things they want from the administration and from the legislature,” including new nuclear plants, owning generation, and investing in energy storage. “I think that they are probably incented to work with the new administration to come up with that list of items that they think they can accomplish again without sacrificing reliability.”
Well before the election, in a statement issued in August responding to Sherrill’s energy platform, PSE&G hinted toward a path forward in its dealings with the state, noting that it isn’t allowed to build or own power generation and arguing that this deregulatory step “precluded all New Jersey electric companies from developing or offering new sources of power supply to meet rising demand and reduce prices.” Of course, the failure to get new supply online has bedeviled regulators and policymakers throughout the PJM Interconnection, of which New Jersey is a part. If Mikie Sherrill can figure out how to get generation online quickly in New Jersey, she’ll have accomplished something more impressive than a rate freeze.
As for ways to accomplish the governor-elect’s explicit goal of keeping price increases at zero, Silverman suggested that large-scale investments could be paid off on a longer timeline, which would reduce returns for utilities. Other investments could be deferred for at least a few years in order to push out beyond the current “bubble” of high costs due to inflation. That wouldn’t solve the problem forever, though, Silverman told me. It could simply mean “seeing lower costs today, but higher costs in the future,” he said.
New Jersey will also likely have to play a role in deliberations happening in front of the Federal Energy Regulatory Commission about interconnecting large loads — i.e. data centers — a major driver of costs throughout PJM and within New Jersey specifically. Rules that force data centers to “pay their own way” for transmission costs associated with getting on the grid could relieve some of the New Jersey price crunch, Silverman told me. “I think that will be a really significant piece.”
Then there’s the hard way — slashing utilities’ regulated rates of return.
In a report prepared for the Natural Resources Defence Council and Evergreen Collective and released after the election, Synapse Economics considered reducing utilities’ regulated return on equity, the income they’re allowed to generate on their investments in the grid, from its current level of 9.6% as one of four major levers to bring down prices. A two percentage point reduction in the return on equity, the group found, would reduce annual bills by $40 in 2026.
Going after the return on equity would be a more difficult, more contentious path than working cooperatively on deferring costs and increasing generation, Silverman told me. If voluntary and cooperative solutions aren’t enough to stop rate increases, however, Sherrill might choose to take it anyway. “You could come in and immediately cut that rate of return, and that would absolutely put downward pressure on rates in the short run. But you establish a very contentious relationship with the utilities,” Silverman told me.
Silverman pointed to Connecticut, where regulators and utilities developed a hostile relationship in recent years, resulting in the state’s Public Utilities Regulatory Authority chair, Marissa Gillett, stepping down last month. Gillett had served on PURA since 2019, and had tried to adopt “performance-based ratemaking,” where utility payouts wouldn’t be solely determined by their investment level, but also by trying to meet public policy goals like energy efficiency and reducing greenhouse gas emissions.
Connecticut utilities said these rules would make attracting capital to invest in the grid more difficult. Gillett’s tenure was also marred by lawsuits from the state’s utilities over accusations of “bias” against them in the ratemaking process. At the same time, environmental and consumer groups hailed her approach.
While Sherrill and her energy officials may not want to completely overhaul how they approach ratemaking, some conflict with the state’s utilities may be necessary to deliver on her signature campaign promise.
Going directly after the utilities’ regulated return “is kind of like making your kid eat their broccoli,” Silverman said. “You can probably make them eat it. You can have a very contentious evening for the rest of the night.”
Current conditions: Unseasonable warmth of up to 20 degrees Fahrenheit above average is set to spread across the Central United States, with the potential to set records • Scattered snow showers from water off the Great Lakes are expected to dump up to 18 inches on parts of northern New England • As winter dawns, Israel is facing summertime-like temperatures of nearly 90 degrees this week.
The Department of the Interior finalized a rule last week opening up roughly half of the largely untouched National Petroleum Reserve-Alaska to oil and gas drilling. The regulatory change overturns a Biden-era measure blocking oil and gas drilling on 11 million acres of the nation’s largest swath of public land, as my predecessor in anchoring this newsletter, Heatmap’s Jeva Lange, wrote in June. The Trump administration vowed to “unleash” energy production in Alaska by opening the 23 million-acre reserve, as well as nearby Arctic National Wildlife Refuge, to exploration. By rescinding the Biden-era restrictions, “we are following the direction set by President Trump to unlock Alaska’s energy potential, create jobs for North Slope communities, and strengthen American energy security,” Secretary of the Interior Doug Burgum said in a statement, according to E&E News. In a post on X, Alaska Governor Mike Dunleavy, a Republican, called the move “yet another step in the right direction for Alaska and American energy dominance.”
The new rule is expected to face challenges in court.“Today’s action is another example of how the Trump administration is trying to take us back in time with its reckless fossil fuels agenda,” Erik Grafe, a lawyer with Earthjustice, an environmental nonprofit group, said in a statement to The New York Times.

For the first time in United Nations climate negotiations, countries attending the COP30 summit in Belém, Brazil, are grappling with the effects of mining the minerals needed for batteries, solar panels, and wind turbines, Climate Home News reported. In a draft text on Friday, a working group at the summit recognized “the social and environmental risks associated with scaling up supply chains for clean energy technologies, including risks arising from the extraction and processing of critical minerals.”
The statement came amid ongoing protests from Indigenous groups, including those from Argentina who warned that the world’s increased appetite for South America’s lithium reserves came at the cost of local water resources for peoples who have lived in regions near mining operations for millennia.
Nearly one fifth of the Environmental Protection Agency’s workforce has opted into President Donald Trump’s mass resignation plan, according to new data E&E News obtained on Friday. As of the end of September, the EPA’s payroll included 15,166 employees, according to data released during the government shutdown, meaning that more than 2,620 employees accepted the “deferred resignation” offer.
Under Administrator Lee Zeldin, the EPA has advanced proposals that even the agency under Scott Pruitt, the top environmental regulator at the start of Trump’s first term, dared not attempt. Zeldin has moved to rescind the endangerment finding, which forms the legal basis for virtually all major climate regulations at the EPA. Zeldin even tried to kill off the popular Energy Star program for efficient appliances, but — as I wrote earlier this month — he backed off the plan.
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The next-generation geothermal company Eavor is preparing to start up its debut closed-loop system at its pilot project in Germany, Think Geoenergy reported. The startup has stood out in the race to commercialize technology that can harness energy from the Earth’s molten core in more places than conventional approaches allow. While rivals such as Fervo Energy, Sage Geosystems, and XGS Energy, pursue projects in the American Southwest, Eavor focused its efforts on Germany, where it saw potential to tap into the lucrative district heating market. Eavor also developed special drilling tools that promised to shave “tens of millions” off the cost of digging wells. As I wrote here last month, the company just completed successful tests of its technology.
BlackRock’s Global Infrastructure Partners inked a deal with the Spanish construction company ACS to form a joint venture to develop roughly $2.3 billion worth of data centers. The 50-50 joint venture will consist of ACS’ existing data-center portfolio, including 1.7 gigawatts of assets under development in Europe, the U.S., and Australia. ACS is contributing its existing portfolio to the business, The Wall Street Journal reported, “in exchange for about 1 billion euros in cash and initial earnout payments of up to 1 billion euros” if the data centers hit certain commercial milestones. “Global demand for data centers is set to grow more than 15 times by 2035, driven by the expansion of AI, cloud migration, and the exponential rise in data volumes,” ACS CEO Juan Santamaria said.
In a first, Swedish scientists have managed to successfully isolate and sequence RNA from an Ice Age wooly mammoth. Researchers at Stockholm University extracted the genetic information from mammoth tissue preserved in Siberian permafrost for nearly 40,000 years. The findings, published in the journal Cell, show that RNA, in addition to DNA and proteins, can be preserved over long periods of time. “With RNA, we can obtain direct evidence of which genes are ‘turned on,’ offering a glimpse into the final moments of life of a mammoth that walked the Earth during the last Ice Age. This is information that cannot be obtained from DNA alone,” Emilio Mármol, lead author of the study, said in a press release.
Editor’s note: This article has been updated to clarify the staff shrinkage at the EPA.
According to a new analysis shared exclusively with Heatmap, coal’s equipment-related outage rate is about twice as high as wind’s.
The Trump administration wants “beautiful clean coal” to return to its place of pride on the electric grid because, it says, wind and solar are just too unreliable. “If we want to keep the lights on and prevent blackouts from happening, then we need to keep our coal plants running. Affordable, reliable and secure energy sources are common sense,” Energy Secretary Chris Wright said on X in July, in what has become a steady drumbeat from the administration that has sought to subsidize coal and put a regulatory straitjacket around solar and (especially) wind.
This has meant real money spent in support of existing coal plants. The administration’s emergency order to keep Michigan’s J.H. Campbell coal plant open (“to secure grid reliability”), for example, has cost ratepayers served by Michigan utility Consumers Energy some $80 million all on its own.
But … how reliable is coal, actually? According to an analysis by the Environmental Defense Fund of data from the North American Electric Reliability Corporation, a nonprofit that oversees reliability standards for the grid, coal has the highest “equipment-related outage rate” — essentially, the percentage of time a generator isn’t working because of some kind of mechanical or other issue related to its physical structure — among coal, hydropower, natural gas, nuclear, and wind. Coal’s outage rate was over 12%. Wind’s was about 6.6%.
“When EDF’s team isolated just equipment-related outages, wind energy proved far more reliable than coal, which had the highest outage rate of any source NERC tracks,” EDF told me in an emailed statement.
Coal’s reliability has, in fact, been decreasing, Oliver Chapman, a research analyst at EDF, told me.
NERC has attributed this falling reliability to the changing role of coal in the energy system. Reliability “negatively correlates most strongly to capacity factor,” or how often the plant is running compared to its peak capacity. The data also “aligns with industry statements indicating that reduced investment in maintenance and abnormal cycling that are being adopted primarily in response to rapid changes in the resource mix are negatively impacting baseload coal unit performance.” In other words, coal is struggling to keep up with its changing role in the energy system. That’s due not just to the growth of solar and wind energy, which are inherently (but predictably) variable, but also to natural gas’s increasing prominence on the grid.
“When coal plants are having to be a bit more varied in their generation, we're seeing that wear and tear of those plants is increasing,” Chapman said. “The assumption is that that's only going to go up in future years.”
The issue for any plan to revitalize the coal industry, Chapman told me, is that the forces driving coal into this secondary role — namely the economics of running aging plants compared to natural gas and renewables — do not seem likely to reverse themselves any time soon.
Coal has been “sort of continuously pushed a bit more to the sidelines by renewables and natural gas being cheaper sources for utilities to generate their power. This increased marginalization is going to continue to lead to greater wear and tear on these plants,” Chapman said.
But with electricity demand increasing across the country, coal is being forced into a role that it might not be able to easily — or affordably — play, all while leading to more emissions of sulfur dioxide, nitrogen oxide, particulate matter, mercury, and, of course, carbon dioxide.
The coal system has been beset by a number of high-profile outages recently, including at the largest new coal plant in the country, Sandy Creek in Texas, which could be offline until early 2027, according to the Texas energy market ERCOT and the Institute for Energy Economics and Financial Analysis.
In at least one case, coal’s reliability issues were cited as a reason to keep another coal generating unit open past its planned retirement date.
Last month, Colorado Representative Will Hurd, a Republican, wrote a letter to the Department of Energy asking for emergency action to keep Unit 2 of the Comanche coal plant in Pueblo, Colorado open past its scheduled retirement at the end of his year. Hurd cited “mechanical and regulatory constraints” for the larger Unit 3 as a justification for keeping Unit 2 open, to fill in the generation gap left by the larger unit. In a filing by Xcel and several Colorado state energy officials also requesting delaying the retirement of Unit 2, they disclosed that the larger Unit 3 “experienced an unplanned outage and is offline through at least June 2026.”
Reliability issues aside, high electricity demand may turn into short-term profits at all levels of the coal industry, from the miners to the power plants.
At the same time the Trump administration is pushing coal plants to stay open past their scheduled retirement, the Energy Information Administration is forecasting that natural gas prices will continue to rise, which could lead to increased use of coal for electricity generation. The EIA forecasts that the 2025 average price of natural gas for power plants will rise 37% from 2024 levels.
Analysts at S&P Global Commodity Insights project “a continued rebound in thermal coal consumption throughout 2026 as thermal coal prices remain competitive with short-term natural gas prices encouraging gas-to-coal switching,” S&P coal analyst Wendy Schallom told me in an email.
“Stronger power demand, rising natural gas prices, delayed coal retirements, stockpiles trending lower, and strong thermal coal exports are vital to U.S. coal revival in 2025 and 2026.”
And we’re all going to be paying the price.