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The community of Cameron Parish, Louisiana has skin in the game.

On paper, the names look like a roster of nursing home residents: Rita and Katrina, Ike and Gustav, Harvey and Laura and Delta.
“I mean, literally, those are all hurricanes since 2005,” James Hiatt, the founder of the environmental justice organization For a Better Bayou, told me. “The storm that hit southwest Louisiana before that was Hurricane Audrey in 1957. So before 2005, we’d gone 50 years without really any storm.”
Now, though, few American communities are more obviously in the crosshairs of climate change than Louisiana’s Cameron Parish. It’s not just the influx of supercharged storms, which have repeatedly wiped out homes and driven those with the means to get out to flee north. The 5,000-or-so remaining residents of the parish, which borders Texas and the Gulf of Mexico in Louisiana’s lower lefthand corner, also share their home with three of the nation’s eight currently operational liquefied natural gas export facilities, according to the Federal Energy Regulatory Commission and the Energy Information Administration. One more is under construction, according to FERC, with two more waiting to break ground and even more in the pipeline — including Calcasieu Pass 2, or CP2, a would-be $10 billion export facility and the largest yet proposed in the U.S., the fate of which has been cast into limbo by the Biden administration’s pause on new LNG export terminal permits.
It is now the Department of Energy’s job to determine whether new terminals are in the “public interest” once their climate impacts are considered. It’s a directive that has ignited debate around the energy security of U.S. allies in Europe, the complicated accounting of methane leaks, and the jurisdiction of the DOE. What has fallen through the cracks in the national conversation, though, is the direct impact this decision has on communities like Cameron, which have been fighting for such a reconsideration for years.
“In southwest Louisiana, where I live, my air here smells like rotten eggs or chemicals every day,” Roishetta Ozane, the founder of Vessel Project of Louisiana, a local mutual aid and environmental justice organization, told me. A mother of six who started the Vessel Project after losing her home to hurricanes Laura and Delta in 2020, Ozane stressed that “we have above-average poverty rates, above-average cancer rates, and above-average toxins in the air. And all of that is due to the fact that we are surrounded by petrochemical, plastic-burning, and industrial facilities, including LNG facilities.”
Hiatt, a Lake Charles native, told me something similar. “The other night, [a terminal] was flaring like crazy, and people were just like, ‘Well, we gotta put up with that if we live here,’” he told me sadly. “That’s a lack of imagination of what better could be.”
Activists like Ozane and Hiatt — and the United Nations — refer to places like Cameron Parish, Calcasieu Parish directly to its north, and the stretch of the Mississippi River in Louisiana known as “Cancer Alley” as sacrifice zones. “The industry wants people to believe that this is rural land, that nobody lives here, that it is just wetlands and swamp,” Ozane said.
LNG export terminals cool natural gas into its liquid form to prepare it for overseas shipping, an energy-intensive process that releases pollutants that environmental groups claim are underreported. Such pollutants often have known health risks, including sulfur dioxide (linked to wheezing, shortness of breath, and chest tightness), volatile organic compounds (suspected and proven carcinogens that also cause eye, nose, and throat irritation, nausea, and damage to livers, kidneys, and the nervous system), black soot (linked to asthma and heart attacks), and carbon monoxide (which can cause organ and tissue damage). All that, of course, is in addition to methane, the base of natural gas and a potent planet-warming greenhouse gas that has cascading global effects, including hurricane intensification.
The region’s history of slavery has made the land around Cameron Parish cheap and easy to exploit, which is part of the reason for the area’s high concentration of terminals. “A lot of predominantly Black communities and predominantly Black neighborhoods, very low-income white neighborhoods, and fishermen towns are where these facilities are located,” Ozane went on. “It’s easy for them to get land there because those masses of land are owned by only a few people — a small family who can say yes to the money and sell that land to industry.”
Politicians, lobbyists, and interest groups like the American Petroleum Institute — which recently announced an eight-figure media campaign promoting natural gas — like to argue that LNG export terminals create American jobs. Both Ozane and Hiatt were rueful when I asked about the industry helping to lift up locals, though. “If the jobs are so good, and the folks are getting the jobs in these communities that are surrounded by these projects, then why is Louisiana still the poorest state in the nation?” Ozane asked me. “Why is our minimum wage still the lowest? And why do we have the highest unemployment rate?” She went on, “We have all of these billion-dollar industries here: They are not hiring local people.”
Hiatt emphasized that it’s hard to understand how little the community is benefitting unless you see it for yourself. “If you drive through Cameron, it looks like the hurricane happened yesterday in a lot of places,” he said. “All these churches are just skeletons, just the framework of what was once there. There’s no grocery store — there’s nothing. If economic prosperity looks like that, then no thank you.” He paused, then corrected himself: “It’s definitely economically prosperous for the owners of these companies,” which are based out of state in places like Virginia and Houston, he said.
These companies often don’t pay state or local taxes; the abatement for Calcasieu Pass LNG alone is valued at $184 million annually, or more than $36,000 per person in Cameron Parish every year — roughly $2,000 more than the area’s average annual income.
While climate activists have celebrated the Biden administration’s LNG pause, local organizers were more reserved in their praise. “We’re not going to take a victory lap here because there’s so much more to do,” Hiatt said, reminding me that “this fight did not happen overnight. This fight for environmental justice has been going for over 40 years in Louisiana.”
Kaniela Ing, the director of the Green New Deal Network, which promotes public support for climate justice, was similarly measured in his enthusiasm when I asked if the pause would have political upsides for Democrats in November. “A lot of the people Biden relied on to win in 2020 — it’s not clear whether they’re motivated enough to turn out again,” he told me. “Especially in BIPOC, low-income communities, and youth voters.” And while the administration’s LNG pause could be viewed as a direct appeal to such a voting bloc, Ing sees the move more as “a highlight reel played at halftime. What matters is how you play the game and right now, we don’t know the plan for the second half.”
An LNG permitting “pause” means nothing for the export terminals that are already under construction or operating. And once the pause is over, more approvals could come. For now, yes, Cameron has its hard-won reprieve. But the status quo of high cancer rates, respiratory health problems, poverty, and environmental exploitation remain unchanged for those who currently call it home.
“My children have asthma,” Ozane said, “and they’re dealing with this pollution every day.”
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With more electric heating in the Northeast comes greater strains on the grid.
The electric grid is built for heat. The days when the system is under the most stress are typically humid summer evenings, when air conditioning is still going full blast, appliances are being turned on as commuters return home, and solar generation is fading, stretching the generation and distribution grid to its limits.
But as home heating and transportation goes increasingly electric, more of the country — even some of the chilliest areas — may start to struggle with demand that peaks in the winter.
While summer demand peaks are challenging, there’s at least a vision for how to deal with them without generating excessive greenhouse gas emissions — namely battery storage, which essentially holds excess solar power generated in the afternoon in reserve for the evening. In states with lots of renewables on the grid already, like California and Texas, storage has been helping smooth out and avoid reliability issues on peak demand days.
The winter challenge is that you can have long periods of cold weather and little sun, stressing every part of the grid. The natural gas production and distribution systems can struggle in the cold with wellheads freezing up and mechanical failure at processing facilities, just as demand for home heating soars, whether provided by piped gas or electricity generated from gas-fired power plants.
In its recent annual seasonal reliability assessment, the North American Reliability Corporation, a standard-setting body for grid operators, found that “much of North America is again at an elevated risk of having insufficient energy supplies” should it encounter “extreme operating conditions,” i.e. “any prolonged, wide-area cold snaps.”
NERC cited growing electricity demand and the difficulty operating generators in the winter, especially those relying on natural gas. In 2021, Winter Storm Uri effectively shut down Texas’ grid for several days as generation and distribution of natural gas literally froze up while demand for electric heating soared. Millions of Texans were left exposed to extreme low temperatures, and at least 246 died as a result.
Some parts of the country already experience winter peaks in energy demand, especially places like North Carolina and Oregon, which “have winters that are chilly enough to require some heating, but not so cold that electric heating is rare,” in the words of North Carolina State University professor Jeremiah Johnson. "Not too many Mainers or Michiganders heat their homes with electricity,” he said.
But that might not be true for long.
New England may be cold and dark in the winter, but it’s liberal all year round. That means the region’s constituent states have adopted aggressive climate change and decarbonization goals that will stretch their available renewable resources, especially during the coldest days, weeks, and months.
The region’s existing energy system already struggles with winter. New England’s natural gas system is limited by insufficient pipeline capacity, so during particularly cold days, power plants end up burning oil as natural gas is diverted from generating electricity to heating homes.
New England’s Independent System Operator projects that winter demand will peak at just above 21 gigawatts this year — its all-time winter peak is 22.8 gigawatts, summer is 28.1 — which ISO-NE says the region is well-prepared for, with 31 gigawatts of available capacity. That includes energy from the Vineyard Wind offshore wind project, which is still facing activist opposition, as well as imported hydropower from Quebec.
But going forward, with Massachusetts aiming to reduce emissions 50% by 2030 (though state lawmakers are trying to undo that goal) and reach net-zero emissions by 2050 — and nearly the entire region envisioning at least 80% emissions reductions by 2050 — that winter peak is expected to soar. The non-carbon-emitting energy generation necessary to meet that demand, meanwhile, is still largely unbuilt.
By the mid 2030s, ISO-NE expects its winter peak to surpass its summer peak, with peak demand perhaps reaching as high as 57 gigawatts, more than double the system’s all-time peak load. Those last few gigawatts of this load will be tricky — and expensive — to serve. ISO-NE estimates that each gigawatt from 51 to 57 would cost $1.5 billion for transmission expansion alone.
ISO-NE also found that “the battery fleet may be depleted quickly and then struggle to recharge during the winter months,” which is precisely when “batteries may be needed most to fill supply gaps during periods of high demand due to cold weather, as well as periods of low production from wind and solar resources.” Some 600 megawatts of battery storage capacity has come online in the last decade in ISO-NE, and there are state mandates for at least 7 more gigawatts between 2030 and 2033.
There will also be a “continued need for fuel-secure dispatchable resources” through 2050, ISO-NE has found — that is, something to fill the role that natural gas, oil, and even coal play on the coldest days and longest cold stretches of the year.
This could mean “vast quantities of seasonal storage,” like 100-hour batteries, or alternative fuels like synthetic natural gas (produced with a combination of direct air capture and electrolysis, all powered by carbon-free power), hydrogen, biodiesel, or renewable diesel. And this is all assuming a steady buildout of renewable power — including over a gigawatt per year of offshore wind capacity added through 2050 — that will be difficult if not impossible to accomplish given the current policy and administrative roadblocks.
While planning for the transmission and generation system of 2050 may be slightly fanciful, especially as the climate policy environment — and the literal environment — are changing rapidly, grid operators in cold regions are worried about the far nearer term.
From 2027 to 2032, ISO-NE analyses “indicate an increasing energy shortfall risk profile,” said ISO-NE planning official Stephen George in a 2024 presentation.
“What keeps me up at night is the winter of 2032,” Richard Dewey, chief executive of the neighboring New York Independent System Operator, said at a 2024 conference. “I don’t know what fills that gap in the year 2032.”
The future of the American electric grid is being determined in the docket of the Federal Energy Regulatory Commission.
The Trump administration tasked federal energy regulators last month to come up with new rules that would allow large loads — i.e. data centers — to connect to the grid faster without ballooning electricity bills. The order has set off a flurry of reactions, as the major players in the electricity system — the data center developers, the power producers, the utilities — jockey to ensure that any new rules don’t impinge upon their business models. The initial public comment period closed last week, meaning now FERC will have to go through hundreds of comments from industry, government, and advocacy stakeholders, hoping to help shape the rule before it’s released at the end of April.
They’ll have a lot to sift through. Opinions ranged from skeptical to cautiously supportive to fully supportive, with imperfect alignment among trade groups and individual companies.
The Utilities
When the DOE first asked FERC to get to work on a rule, several experts identified a possible conflict with utilities, namely the idea that data centers “should be responsible for 100% of the network upgrades that they are assigned through the interconnection studies.” Utilities typically like to put new transmission into their rate base, where they can earn a regulated rate of return on their investments that’s recouped from payments from all their customers. And lo, utilities were largely skeptical of the exercise.
The Edison Electric Institute, which represents investor-owned utilities, wrote in its comments to FERC that the new rule should require large load customers to pay for their share of the transmission system costs, i.e. not the full cost of network upgrades.
EEI claimed that these network costs can add up to the “tens to hundreds of millions of dollars” that should be assigned in a way that allows utilities “to earn a return of and on the entirety of the transmission network.”
In short, the utilities are defending something like the traditional model, where utilities connect all customers and spread out the costs of doing so among the entire customer base. That model has come under increasing stress thanks to the flood of data center interconnection requests, however. The high costs in some markets, like PJM, have also led some scholars and elected officials to seriously reconsider the nature of utility regulation. Still, that model has been largely good for the utilities — and they show no sign of wanting to give it up.
The Hyperscalers
The biggest technology companies, like Google, Microsoft, and Meta, and their trade groups want to make sure their ability to connect to the grid will not be impeded by new rules.
Ari Peskoe, an energy law professor at Harvard Law School, told me that existing processes for interconnection are likely working out well for the biggest data center developers and they may not be eager to rock the boat with a federal overhaul. “Presumably utilities are lining up to do deals with them because they have so much money,” Peskoe said.
In its letter to FERC, the DOE suggested that the commission could expedite interconnection of large loads “that agree to be curtailable.” That would entail users of a lot of electricity ramping down use while the grid was under stress, as well as co-locating projects with new sources of energy generation that could serve the grid as a whole. This approach has picked up steam among researchers and some data center developers, although with some cautions and caveats.
The Clean Energy Buyers Association, which represents many large technology companies, wrote in its comment that such flexibility should be “structured to enable innovation and competition through voluntary pathways rather than mandates,” echoing criticism of a proposal by the electricity market PJM Interconnection that could have forced large loads to be eligible for curtailment.
The Data Center Coalition, another big tech trade group representing many key players in the data center industry, emphasized throughout their comment that any reform to interconnection should still allow data centers to simply connect to the grid, without requiring or unduly favoring “hybrid” or co-location approaches.
“Timely, predictable, and nondiscriminatory access to interconnection service for stand-alone load is… critical… to the continued functioning of the market itself,” the Data Center Coalition wrote.
The hyperscalers themselves largely echoed this message, albeit with some differences in emphasis. They did not want any of their existing arrangements — which have allowed breakneck data center development — to be disrupted or to be forced into operating their data centers in any particular fashion.
Microsoft wrote that it was in favor of “voluntarily curtailable loads,” but cautioned that “most data centers today have limited curtailment capability,” and worried about “operational reliability risks.” In short, don’t railroad us into something our data centers aren’t really set up to do.
OpenAI wrote a short comment, likely its first ever appearance in a FERC docket, where it argued for “an optional curtailable-load pathway” that would allow for faster interconnection, echoing comments it had made in a letter to the White House.
Meta, meanwhile, argued against any binding rule at all, saying instead that FERC “should consider adopting guidance, best practices, and, if appropriate, minimum standards for large load interconnection rather than promulgating a binding, detailed rule.” After all, its deploying data centers gigawatts at a time and has been able to reach deals with utilities to secure power.
The Generators
Perhaps the most fulsome support for the broadest version of the DOE’s proposal came from the generators. The Electrical Power Supply Association, an independent power producer trade group, wrote that more standardized, transparent “rules of the road” are needed to allow large loads like data centers “to interconnect to the transmission system efficiently and fairly, and to be able to do so quickly.” It also called on FERC to speed up its reviews of interconnection requests.
Constellation, which operates a 32-gigawatt generation fleet with a large nuclear business, said that it “agrees with the motivations and principles outlined in the [Department of Energy’s proposal] and the need for clear rules to allow the timely interconnection of large loads and their co-location with generators.” It also called for faster implementation of large load interconnection principles in PJM, the nation’s largest electricity market, “where data center development has been stymied by disagreements and uncertainty over who controls the timing and nature of large load interconnections, and over the terms of any ensuing transmission service.” Constellation specifically called out utilities for excessive influence over PJM rulemaking and procedures.
Constellation’s stance shouldn’t be surprising, Peskoe told me. From the perspective of independent power producers, enabling data centers to quickly and directly work with regional transmission organizations and generators to come online is “generally going to be better for the generators,” Peskoe said, while utilities “want to be the gatekeeper.”
In the end, the fight over data center interconnection may not have much to do with data centers — it’s just one battle after another between generators and utilities.
The senator spoke at a Heatmap event in Washington, D.C. last week about the state of U.S. manufacturing.
At Heatmap’s event, “Onshoring the Electric Revolution,” held last week in Washington, D.C. every guest agreed: The U.S. is falling behind in the race to build the technologies of the future.
Senator Catherine Cortez Masto of Nevada, a Democrat who sits on the Senate’s energy and natural resources committee, expressed frustration with the Trump administration rolling back policies in the Inflation Reduction Act and Infrastructure Investment and Jobs Act meant to support critical minerals companies. “If we want to, in this country, lead in 21st century technology, why aren’t we starting with the extraction of the critical minerals that we need for that technology?” she asked.
At the same time, Cortez Masto also seemed hopeful that the Senate would move forward on both permitting and critical minerals legislation. “After we get back from the Thanksgiving holiday, there is going to be a number of bills that we’re looking at marking up and moving through the committee,” Cortez Masto said. That may well include the SPEED Act, a permitting bill with bipartisan support that passed the House Natural Resources Committee late last week.
Friction in the permitting of new energy and transmission projects is one of the key factors slowing down the transition to clean energy — though fossil fuel companies also have an interest in the process.
Thomas Hochman, the Foundation of American Innovation’s director of infrastructure policy, talked about how legislation could protect energy projects of all stripes from executive branch interference.
“The oil and gas industry is really, really interested in seeing tech-neutral language on this front because they’re worried that the same tools that have been uncovered to block wind and solar will then come back and block oil and gas,” Hochman said.
While permitting dominated the conversation, it was not the only topic on panelists’ minds.
“There’s a lot of talk about permitting,” said Michael Tubman, the senior director of federal affairs at Lucid Motors. “It’s not just about permits. There’s a lot more to be done. And one of those important things is those mines have to have the funding available.”
Michael Bruce, a partner at the venture capital firm Emerson Collective, thinks that other government actions, such as supporting domestic demand, would help businesses in the critical minerals space.
“You need to have demand,” he said. “And if you don’t have demand, you don’t have a business.”
Like Cortez Masto, Bruce lamented the decline of U.S. mining in the face of China’s supply chain dominance.
“We do [mining] better than anyone else in the world,” said Bruce. “But we’ve got to give [mining companies] permission to return. We have a few [projects] that have been waiting for permits for upwards of 25 years.”