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From the national to the state to the local level, the state is about to hold some of the country’s most crucial elections.

In 2022, the Arizona Republic published a sentence many Democrats had dreamed of reading for decades: “Arizona,” the paper announced, “is a blue state.”
At the time, it felt true. In 2020, Joe Biden won the Grand Canyon State — only the second time a Democrat had done so since Arizona broke for Harry Truman in 1952 — and Democrat Mark Kelly defeated Republican Sen. Martha McSally in a special election to fill the late John McCain’s Senate seat, a victory that helped the Inflation Reduction Act get over the finish line. The 2022 midterm elections confirmed that the Democrats’ wins in the state hadn’t just been a one-time occurrence: Kelly successfully defended his seat, securing a full term; Katie Hobbs won the governorship; and Adrian Fontes beat a January 6 participant to become the secretary of state, Democrats all.
With the 2024 election still a little more than a week away, it’s too soon to tell whether the blue state proclamations of 2022 were premature. But Arizona hasn’t been looking terribly cerulean. In 2023, the Republican-held state legislature passed eight of 16 anti-environment bills introduced and stranded 22 pro-environment bills without committee hearings. Republican voter registration in the state has also swelled since 2016 as Democratic rolls stayed relatively stagnant, giving the GOP an edge in a place where 10,457 votes can make all the difference.
Arizona is just one state out of 50 (or 11 electoral votes out of 538, if you prefer), but it represents a curious microcosm of the high-stakes climate and energy elections happening all over the country this November. Or perhaps it is not so curious: Arizona is on the front lines of the climate-related impacts of droughts, longer and nastier heat waves, ozone pollution, and wildfires, while also being in a position to weigh the trade-offs of crucial clean energy developments like building new energy transmission, critical mineral mining, and utility-scale solar. “It’s like an incubator. There’s just so much happening here, it’s ready to burst,” Jane Conlin, a co-leader of the Tucson chapter of the Citizens' Climate Lobby, which has been engaging in get-out-the-vote efforts with the Environmental Voter Project, told me.
Aside from its electoral college allocations, the most consequential race in Arizona this cycle will be for outgoing Independent Senator Kyrsten Sinema’s seat. The state is currently leaning slightly toward Democratic Representative Ruben Gallego, who could help stem a total hemorrhaging of blue seats from the Senate — which, in turn, would have implications for the passage of any decarbonization legislation in the next administration.
Two U.S. House elections in Arizona could similarly help determine the balance of power on Capitol Hill come January. AZ-01 is the wealthiest congressional district in the state, in the northeastern corner of Phoenix’s Maricopa County, where a former E.R. doctor is trying to unseat a seven-term Republican incumbent in a battle that has centered on abortion access. (The district is also home to the Rio Verde Foothills, which made national headlines in 2022 when Scottsdale cut off its water supply due to drought-related shortages.)
But it’s the other race, in the sixth congressional district spanning the suburbs of Tucson, that looks more like a proxy battle between different climate ideologies. Kirsten Engel — who previously worked for the U.S. Environmental Protection Agency and serves as the co-director of the Environmental Law Program at the University of Arizona — is challenging Juan Ciscomani, a Trump-endorsed moderate conservative who has backed residential solar projects, promoted himself as an advocate for a “secure water future,”and, earlier this year, co-sponsored a bill seen as a first step toward a carbon border tax. (As his opponents quickly point out, he also voted against the IRA; Ciscomani has also been tied to a groundwater scandal involving a Saudi Arabian-owned alfalfa farm.)
Engel previously lost a tight election against Ciscomani in 2022, and has made abortion a centerpiece of her campaign, too. But she has also gone aggressively after the Republican for his alignment with the mining industry, including his support for a proposed open-pit copper mine that opponents say will pollute Tucson’s air and waterways; supporters, meanwhile, say it’s critical to create a domestic supply chain for the energy transition. The League of Conservation Voters, which identified the sixth congressional district election as one of its priority races, is running ads in the state playing up this pollution angle.
Engel herself has slammed the proposed mine, which would be built on public lands, as a “giveaway” to a foreign mining company, and touted the need to protect the region’s “spectacular scenic vistas and the tourism economy.” She has also sought to go toe-to-toe with Ciscomani on water conservation, though as Grist has reported, drought and water rights can be tricky for Arizona politicians to run on because voters don’t have a firm grasp of how the complicated policies work.
The future of climate policy at the regional and municipal levels in Arizona is also in play. Democrats could potentially flip the balance of power in the state House and Senate, each branch currently having just a one-seat Republican advantage, and restart movement on the slate of stalled pro-environmental bills. (The Democratic governor’s term runs through 2026.) “The state legislature in Arizona is so critical,” John Qua, the campaign manager of Lead Locally, told me. “Not only does building a democratic trifecta get the state closer to passing policy that tackles climate change in some of the ways we might more typically understand it — like moving towards clean energy — but it also makes it much likelier that the state legislature will pass water conservation policy.”
The 11 races are “all at a razor-thin margin,” Qua told me, though climate is unlikely to be the issue that tips the balance in any of them. That goes for just about any race in Arizona — except the state’s Corporation Commission, which Heatmap’s Emily Pontecorvo covered earlier this week. Currently, the ACC is operating with a four-to-one Republican majority, but with three Democrats, two Green party candidates, and three Republicans (including an incumbent) running to fill three seats, there’s a wide-open chance that candidates sympathetic to clean energy policy, including the state’s massive solar opportunity, could take control.
“Arizona could lead the world in solar power if politicians would only let it,” Nathaniel Stinnett, the founder and executive director of the Environmental Voter Project, told me. “But that isn’t going to happen unless the climate movement starts showing up in unstoppable numbers whenever there’s an election.”
Conlin, who co-leads the Tucson chapter of the Citizens’ Climate Lobby, has been working on the ground to reach the 230,000 potential first-time environmental voters that Stinnett and his team have identified in the state. (EVP numbers released earlier this week showed that those who vote based on climate issues were about 20% more likely to have submitted an early vote than the average voter.) During a recent folklife festival CCL volunteers attended, “I think about only 25% of people [we engaged with] were really aware of the Arizona Corporation Commission,” Conlin told me. But she’s excited nevertheless: This year, the ACC poll is on the front of Arizonans’ ballots, rather than the back, making it harder for even low-information voters to overlook.
The state is also a case study of how an elected body as small and seemingly insignificant as a school board can make a difference in the progress toward decarbonization. The Tucson Unified School District board of governors will vote next week on a climate action plan that would set a goal of reaching net-zero emissions by 2045. If successful, TUSD would be one of the first school districts in the nation to have implemented such a plan.
Arizona is not the only state in the country that, as Colin put it, feels “on this cusp of being able to reach out — not only to see a 50% cut in emissions but 100%. It’s doable, it’s within reach.” Pennsylvania and Michigan voters will also have opportunities to elect politicians who will advance climate legislation, and voters in Washington, California, and New York can defend their states’ progress. But it’s Arizona where the stakes seem especially immediate — and high. “It’s supposed to be 96 [degrees Fahrenheit] here today,” Conlin marveled when we spoke this week, at the end of October.
I could hear the weariness in the voices of the organizers I spoke to after a long, hard-fought season; candidates are set to make their final pitches to voters next week. Early-voting ballots are already in the mail or in hand. The CCL has just one final day of canvassing planned, on November 2. The polls will close three days later, at 7 p.m. local time, and then the count will begin.
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The July 4 heat wave showed just how far the metropolis has to go to reach its decarbonization goals.
New York City’s decarbonization plan has stalled. The events of this year’s Fourth of July weekend all but prove it.
The temperature in the city reached as high as 100 degrees Fahrenheit on Thursday, July 2, the hottest it’s been here in 14 years. As New Yorkers blasted their air conditioners to stay cool, utilities drew on all of New York’s resources to serve the resulting electricity demand for cooling. These included a fleet of dual-fuel power plants, which can burn both oil and natural gas and encompasses many of its peakers, which turn on to deal with spikes of demand.
Those dual-fuel plants pushed over 10 gigawatts of electricity onto the grid on the evening of July 1— about a third of the total load in the state — and hit similar peaks on the 2nd and 3rd. The peaker fleet owned and operated by the New York Power Authority was operational for over two-thirds of the heat wave, which persisted for four consecutive days, while some ran nonstop from 7 a.m. July 2 to 3 a.m. July 4, according to NYPA.
In response to questions about the use of its peakers during the heat wave, a NYPA spokesperson told me, “During times of peak energy demand, like last week’s heat wave, the state’s independent grid operator called upon NYPA’s Small Natural Gas Power Plants to run well beyond their typical usage to meet high energy needs and prevent localized blackouts.”
While specific generator information is a protected trade secret, they said, “capacity suppliers are critical resources to meet system peak loads like those experienced during the recent heatwave.”
And yet still, over 100,000 people lost power during the heat wave. Real-time electricity prices in the area of the New York grid that includes the city got as high as $1,465 per megawatt-hour on the evening of July 3, according to data collected by Grid Status.
At the same time, the latest addition to New York’s non-carbon electricity generation fleet, a transmission line from Quebec that can transmit up to 1,250 megawatts known as the Champlain Hudson Power Express, was struggling. It experienced an unplanned outage on July 1, the first day of the heat wave, followed by a second outage beginning on July 4 that still had not been resolved as of Friday.
Since 2014, the city has had an aspirational goal of reducing emissions by 80% of its 2005 levels by 2050. CHPE was a major part of that plan, which also included offshore wind and utility-scale solar. There has been progress: Of the 1,000 megawatts of solar the city aims to have installed by 2030, about two thirds have been built. Even so, about 90% of New York City’s electricity came from fossil fuels in 2025, according to the city’s comptroller.
Why the difficulty decarbonizing? Blame a mixture of policy and geography. New York City is dense and has a lot of old buildings with old heating systems. Reducing consumption of fossil fuels requires getting cars off the road (congestion pricing) and retrofitting buildings with electric appliances (Local Law 97).
But that’s the demand side — the supply side is far trickier. Utility-scale non-carbon-emitting power on the orders of hundreds of megawatts or a gigawatt will have to be built elsewhere and piped in via transmission lines. That means offshore wind, solar (ideally with battery storage), and maybe one day nuclear power.
To the extent New York City can build solar and storage locally, it means dealing with a thicket of building regulations and local opposition. Efforts to shut down or replace peaker plants in the city have run into a brick wall at the New York Independent System Operator, which has declared that at least some peakers will have to stay online through the end of the decade to maintain system-wide reliability.
The only other new source of carbon-free power currently under construction is the offshore wind project Empire Wind, due to come online in 2027. NYISO said last year that without CHPE, Empire, and two local transmission projects planned to enter service by 2030, New York City would be “deficient in the summer” through 2030.
Of course developers have scrapped several other offshore wind projects over the years, whether due to problems procuring the right size turbine or the Trump administration buying out their lease. And though New York Governor Kathy Hochul pledged last summer to develop at least a gigawatt of new nuclear capacity in the northern region of the state, that is probably a decade away from fruition.
Meanwhile the Clean Path transmission line, which was meant to connect New York City to several gigawatts of new wind, solar and hydropower, saw its contracts canceled in late 2024 as its projected costs continued to rise. Last year, utility regulators shut down an effort by the state-run New York Power Authority to take it over as a “priority transmission project,” questioning whether it was “needed expeditiously” to meet downstate reliability needs and arguing that the project “will not be needed to serve substantial amounts of generation until well after 2033, and possibly not until 2040.”
While the city has some utility-scale battery storage systems, would-be developers have faced intense local opposition. Fullmark Energy, for instance, scrapped a planned 650-megawatt storage project after protests from political figures, including frequent mayoral candidate Curtis Sliwa. A dispute over another battery storage project in Queens has escalated into accusations of assault leveled by Councilmember Phil Wong, who called for a criminal investigation into what he said was an assault by a contractor for a project against his staffer.
So what’s left for New York City to do?
Any near-term progress will likely come from increasing efficiency and adding marginal generation capacity, as opposed to large-scale new projects and decommissioning of power plants.
“We need to max out our energy efficiency gains from Local Law 97,” former New York City Chief Climate Policy Advisor Daniel Zarelli told me, referring to a 2019 law mandating steep reductions in emissions from large buildings in the city, which came into effect two years ago. He also called for a further“push on batteries and behind the meter solar, clean energy, and energy efficiency.”
Already across the state, behind-the-meter solar is shaving off peak power demand. On the afternoon of July 2, behind-the-meter solar accounted served about 4.5 gigawatts to users, according to NYISO and Grid Status data.
Going forward, Zarelli said, the city should use its purchasing and planning power — as it did with CHPE — for projects like resurrecting Clean Path. “We need to be starting now. Maybe it’s not by 2030, but soon after we could be getting the benefit of that.”
“Battery developers started to see interconnection costs that were around 30 or 40 times what is standard,” Patrick Robbins, director of the Utility Customers Association told me. “It just means that new battery projects completely don’t pencil out and so we have a de facto moratorium on new [battery] projects.”
Advocates for solar and storage have blamed Con Edison for the city’s slow progress there, claiming that changes in the interconnection process have made it essentially cost prohibitive for battery storage developers to move forward on new projects.
Some of these fights have landed in front of New York’s Public Service Commission. In a filing, the city cited data from Con Edison showing that “the interconnection costs for some projects … have increased by thousands of percent,” citing one project whose interconnection costs jumped from $640,000 to over $35 million due to changes in how Con Edison attributed grid costs from new projects.
"Battery storage is essential to New York's clean energy future, and Con Edison strongly supports the development of energy storage when projects are deployed at the right locations, at the appropriate scale, and with operating parameters that provide the greatest benefit to customers and the electric grid,” a Con Edison spokesperson told me. “Because grid constraints vary across our system — from neighborhood‑level distribution lines to major transmission corridors — the location of a battery ultimately determines how much benefit it can deliver to the grid and to customers.”
There were 115 megawatts of battery storage operational in New York City at the end of last year, according to Con Edison, and 865 megawatts of projects with interconnection agreements. Peak load in the region is about 10,000 megawatts, meaning that these new projects would meaningfully alter the way the utility serves its customers.
Con Edison has claimed in a regulatory filing that the concentration of projects could lead to “significant impacts from BESS charging on infrastructure upstream of primary feeders,” necessitating the changes to its interconnection process. The city claimed in its filing that the added cost has “understandably chilled ongoing development activity at a time when New York City needs more supply resources capable of serving peak demand.”
When I reached out to the Mayor’s Office of Climate & Environmental Justice about the dispute, I received a statement in return from New York City Chief Climate Officer Louise Yeung: “Expanding battery storage capacity will be critical to New York City’s clean energy future, as extreme climate events continue to strain our grid system,” she said. “The City is working across agencies and communities to ensure battery energy storage projects are deployed safely and can provide reliable power when New Yorkers need it most.”
As for residential solar and storage, it will likely take years for those distributed resources to become a regular part of New York City’s energy landscape. There’s only one fully permitted and approved residential storage system allowed in New York City, which was installed earlier this year by Brooklyn Solar Works. Negotiating approvals with city agencies including the Department of Buildings and the New York City Fire Department took around six years, the company’s vice president of sales, Steve Nelson, told me.
“It’s New York City. We’re expecting there to be some level of bureaucracy and some lift to get that stuff approved,” Nelson said. “But what we also lack is a ready, readily accessible residential battery that meets the criteria that these departments have set.”
All that adds up to both a practical and a political gap for decarbonization, Zarelli told me.
“Batteries are a great way to connect the climate agenda and the affordability agenda, and it’s in the mayor’s control — it’s the regulatory apparatus at FDNY,” he said. “That’s a big near-term play that I think would make a big difference.”
Earlier this year, New York City Councilmember James Gennaro introduced a bill to amend the fire code to relax some battery storage permitting and safety requirements. But that still leaves the city’s decarbonization advocates with many big fish to fry.
“It’s a challenging future that’s still out in front of us, and how to navigate that is really difficult. But it’d be good if we were actually aligned on what our goals were as a society,” Zarelli said.
Rates were up 17% year over year in June, according to the latest Electricity Price Hub update, with another increase on the way.
With higher temperatures come higher electricity bills. Whether through higher seasonal charges or greater usage, Americans across the country were paying more for electricity in June.
In Virginia, the epicenter of the data center boom, the typical household electricity bill was $192 in June, up from $172 in June of last year, according to the latest data from the Heatmap and MIT’s Electricity Price Hub. Rates, meanwhile, were about 18 cents per kilowatt-hour, compared to just over 15 cents in June of last year, a 12% hike. Rates were also up from the end of last year, when they were about 15.5 cents.
The rate increase is largely due to prices set by Virginia’s largest utility, Dominion. Its rates are up 8% so far this year, according to MIT researchers, and 17% over the past 12 months, the result of a base rate increase that took effect at the beginning of the year. The average base rate alone is up 7.5% year over year for the average Dominion customer.
But that’s not all: The fuel portion of the bill is rising $8 a month for the typical customer, Dominion said according to local media reports, as a result of rising costs. The fuel charge went into effect at the beginning of July. Already, Dominion customers are paying about $78 per month for the generation portion of their electricity bill, according to Heatmap-MIT data.
The price hike will likely increase pressure on Dominion as it seeks to sell itself to Florida utility and energy developer NextEra in a $67 billion deal announced in May.
Earlier this week, Virginia's lieutenant governor Ghazala Hashmi sent a detailed letter to the State Corporation Commission, Virginia’s utility regulator, with 64 questions about the proposed merger. She said the deal “carries unprecedented implications for Virginia’s consumers and regulatory landscape.”
Hashmi asked regulators to extend their review of the deal beyond the six-month period mandated by its utility regulations, writing that “forcing this process into the six-month timeline will render an already inadequate period completely unworkable.”
In May, when the deal was announced, NextEra said it would provide over $2 billion of bill credits over two years to Dominion customers in Virginia, North Carolina, and South Carolina, which Dominion executives estimated would add up to $10 per month over the two years.
On the India-Australia uranium deal, a U.S. general’s warning, and Chicago’s VPP
Current conditions: China and Taiwan are bracing for Super Typhoon Bavi to make landfall as possibly the strongest storm either country has faced in years • Utah’s Babylon fire has torched at least 103,000 acres already, and was just 25% contained as of this morning • New York City faces flooding as the thunderstorms that began yesterday continue into Saturday.

When the heat dome roasting the Eastern United States hit a peak last week, I told you that PJM Interconnection could hardly keep up with its own forecasts for demand. While the nation’s largest power grid operator had projected summertime demand for electricity would top out at 156 gigawatts, analysts last week predicted PJM’s load during the heat wave would hit the all-time record set in 2006 of just under 166 gigawatts. On July 2, it far surpassed even that: The 13-state grid set a new all-time system record of more than 168 gigawatts of demand, the grid operator confirmed Thursday. Wind and solar played major roles in supplying the power needed to avoid blackouts. “Solar, wind, and demand-side solutions showed up in a big way during this heatwave to keep the lights on and homes cool,” Jon Gordon, a senior director at the industry group Advanced Energy United, said in a statement. “Deploying more of these solutions, as well as energy storage, would help PJM avoid needing to call on so many expensive and dirty backup diesel generators and peaker units in the future.”
The milestone comes as PJM is scrambling to rewrite its rules, as Heatmap’s Matthew Zeitlin has covered, to figure out how to bring more generation online and allow more large power users such as data centers to patch onto the system.
Fervo Energy just drilled another well for its flagship Cape Station project in Utah. This one, as Matthew wrote yesterday, is 19,448 feet deep, includes a 7,500-foot lateral span underground, and took just 21 days to drill. While that time matches the same number of days the project’s Phase I wells required, this one is, on average, nearly 35% deeper, with a 50% wider lateral extension. “Today, we are drilling deeper, hotter wells that will produce multiples more [megawatts] per well than our Project Red pilot, and we are doing it in a fraction of the time,” CEO Tim Latimer said in a statement.
In the race to build out more nuclear power, China is far and away in first place, with more than three dozen reactors under construction. Trailing in second is India, with about half a dozen. But New Delhi wants more, as evidenced by last winter’s legal reform to open the subcontinent’s atomic power industry to exports for the first time in nearly decades, which I told you about back in December. Unlike other countries that build first and find fuel later, India is devoid of major uranium reserves, which is partly why its government is so keen on thorium fuel. Until that works out, however, New Delhi is locking down other supplies. On Thursday, Prime Minister Narendra Modi inked a deal with the Australian government to increase India’s imports of uranium. The agreement, signed in Melbourne yesterday morning, does not specify the volumes of metal India plans to import. The deal’s significance goes beyond just reactor fuel. India is infamously one of the biggest countries to refuse to sign the global Treaty of Non-Proliferation of Nuclear Weapons, and in fact was the first nation to develop an atomic weapon after the pact was agreed among most countries on Earth. Australia, a major uranium miner, previously refused to sell fuel to any country that wasn’t a signatory to the treaty. But Canada eased its rules to ink a uranium deal with India in March. While the Associated Press noted that Australia’s “leaders historically ruled out” such a deal with New Delhi, “Canberra’s position has eased.”
In the U.S., meanwhile, the Nuclear Regulatory Commission this week continued its regulatory overhaul efforts by proposing the biggest changes to how the agency applies the National Environmental Policy Act in years. Under the new NEPA rule, the NRC would streamline permitting, eliminate the need to submit a draft of a project’s environmental impact statement, and add new exemptions to conducting environmental reviews.
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The series of equity deals President Donald Trump struck with individual mining companies to bolster the U.S. government’s portfolio of domestic producers of critical minerals certainly made members of the Biden administration jealous. But the U.S. Army’s former chief operating officer says a huge policy gap remains. Speaking on a podcast from The Northern Miner, Flynn, who previously commanded the U.S. Army Pacific, suggested Trump’s approach was too piecemeal. “One of the central problems is we tend to fund a mine, a processor, or a technology as a standalone project versus trying to pull a consortium of projects together, a consortium of companies and leaders together, that combine skilled workers, equipment, metallurgists, transportation needs, and customers,” Flynn said, hanging on that last word in an apparent attempt to emphasize the “Trump mineral paradox” I was telling you about yesterday. “I’m not sure that’s what our plan is.” He added that he’s “being critical now” because mining projects require five- to 10-year funding commitments. “This is what China did to build their system out,” he said. “That’s what they did a number of years ago. We’re almost taking a page out of their book.”
The proposal Chicago’s utility Commonwealth Edison put out for a battery-based “scheduled dispatch virtual power plant” has won state approval. On Wednesday, Utility Dive reported that the Illinois Commerce Commission gave the company the green light last week to replace the more limited VPP proposal the ComEd pitched last year, which was scrapped after the state passed legislation to support the expansion of battery storage capacity across northern Illinois. The new VPP program “is an important step in bolstering the potential of customer-sited energy resources to make the grid more resilient during periods of peak demand while helping customers receive additional value for their support at a time when supply costs are rising,” Andrew Plenge, ComEd’s vice president of strategy and energy policy, said in a press release. The VPP is poised to go live next year.
Hyundai is so committed to developing clean hydrogen that the South Korean automaker is now building America’s leading green steel project in Louisiana. But if skeptics of the fuel think that’s billions of dollars thrown in the toilets, just wait until they hear about the company’s newest facility. On Thursday, Hydrogen Insight reported that the company had opened its HTWO Energy Cheongju plant at a public waste treatment facility with the goal of producing 500 kilograms of hydrogen per day from sewage sludge broken down in an anaerobic digester and refined through two additional processes. “At a time when energy security is important, this is significant in that it establishes a system for directly producing and supplying energy using urban infrastructure,” Lee Ho-hyun, second vice-minister of the Ministry of Climate, Energy and Environment, said in a statement.