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There is no dearth of advice on the internet about how to lower your personal carbon emissions, but if we had found any of it completely satisfying, we wouldn’t have embarked on this project in the first place.
Our goal with Decarbonize Your Life is to draw your attention to two things — the relative emissions benefits of different actions, as well as the relative structural benefits. (You’ll find everything you need to know about the project here.) For the first, we needed some help. So we shared our vision with WattTime, a nonprofit that builds data-driven tools to help people, companies, and policymakers figure out how to reduce emissions, and lucky for us, they were excited to support the project.
“So many people out there feel helpless when it comes to addressing the climate crisis, but we believe that anyone, anywhere should have the tools and information they need to make a difference,” Henry Richardson, a senior analyst at WattTime, told me as we were wrapping up this project. “So we love the idea of helping average consumers understand which actions actually available to them can meaningfully contribute to reducing climate pollution. We want to help people prioritize those higher-impact activities that can mitigate climate change faster.”
WattTime’s claim to fame is building an API that calculates the emissions impact of using the grid at a given time and place. Users can then shift their energy consumption to times when the grid is cleaner or to build renewables in places where they will reduce emissions the most.
In an ideal world, we would have taken a similar time- and place-based approach in calculating the emissions savings of each energy-related action on our list. Switching to an EV if you live somewhere with very clean power will reduce emissions more than if you live somewhere with lots of coal plants, and likewise, getting rooftop solar if you live somewhere with coal-fired electricity is more effective than in areas with a cleaner grid. But when we started to game it out, we realized that level of exactitude would be, if not exactly impossible, certainly insanity-inducing.
Instead, WattTime helped us calculate the effect of each action if it was undertaken by an “average American household” — that is, one that consumes an average amount of electricity per year, drives an average number of miles in an average car per year, uses an average amount of energy for space heating, et cetera. WattTime also pulled data from publicly available sources like the Environmental Protection Agency, the Department of Energy, and the Energy Information Administration, to estimate the baseline emissions and savings of a given action. We ultimately made two calculations for each action to account for two different ways of estimating the emissions from using the electric grid:
While the first method gives us a picture of how much good each action can do in an immediate sense, the second gives us a picture of how much good it can do over time. For example, using the first method, buying clean power came out on top, with rooftop solar offering the potential to cut CO2 by about 5.7 metric tons per year, while switching to an electric vehicle would cut about 3 metric tons per year. But using the second method, car-related actions won out, showing EVs cutting CO2 by 4.6 metric tons per year, and rooftop solar cutting 1.4 metric tons per year. The truth is probably somewhere in the middle.
To calculate the emissions savings from dietary changes and food waste management, we turned to two more partners: HowGood, a data platform for food system lifecycle analysis, and ReFED, which collects similar data for food waste. As with energy, we used federal data from the U.S. Department of Agriculture to estimate the average American diet and ReFED’s estimates for the average American food waste mix (though note that those are for an individual, not for a household). From there, WattTime helped us determine that, for instance, just by replacing the beef in your diet with chicken, you could save nearly 2.5 metric tons of emissions each year — almost as much as you could save by going vegan.
Because we used averages and sought to simplify our list with actions like “electrify your space heating system,” rather than estimating the impact of every permutation like “switch from a propane furnace in Colorado with X efficiency to a cold climate heat pump with Y efficiency,” our estimates of emissions reductions are rough approximations and not reflective of real-world scenarios.
You’ll see that while these calculations certainly informed our ranking, they were not the sole metric we used to arrange this list. A quantitative analysis alone could not answer our question about the most “high-leverage” actions, so we used our reporting and expertise as climate journalists to fill in that last, crucial gap. Car-related actions and rooftop solar were neck-and-neck by the numbers, but we are confident that getting an EV (if you need to have a car) is more unambiguously necessary for the energy transition than getting rooftop solar. Similarly, while eating less meat can hugely reduce the carbon tied to an individual’s diet, the ripple effect it has on agricultural carbon emissions is less direct and harder to parse than the effect you can have by electrifying all your appliances and shutting down your natural gas account.
Getting an EV:
WattTime — 2.9 mtCO2/yr
Cambium — 4.5 mtCO2/yr
Structural benefits: Destroying demand for oil; increasing demand for charging stations; improving local air quality and chipping away at the social license for operating an internal combustion engine.
Getting rooftop solar:
WattTime — 5.7 mtCO2/yr
Cambium — 1.4 mtCO2/yr
Structural benefits: Get clean energy on the grid faster than utility-scale projects; influence neighbors; reduce electric demand in your neighborhood; reduce strain on grid if paired with a battery and part of a “virtual power plant”
Air-sealing and insulation:
WattTime — 1.2 mtCO2/yr
Structural benefits: Reduce strain on grid and need for grid investment; level out electricity demand to avoid the need to activate dirty “peaker” gas plants; prepare your home for cheaper, more even, and efficient heating and cooling
Switching to a heat pump for space heating:
WattTime — 1.4 mtCO2/yr
Cambium — 1.6 mtCO2/yr
Switching from a gas stove to an induction stove:
WattTime — Roughly even
Cambium — 0.1 mtCO/yr
Switching to a heat pump for water heating:
WattTime — 0.8 mtCO2/yr
Cambium — 1.6 mtCO2/yr
Switching from a natural gas-powered dryer to a heat pump dryer:
WattTime — Roughly even
Cambium — 0.1 mtCO/yr
Structural benefits: Increase demand for and reduce price of electric and efficient appliances; build a case for policies that wind down fossil fuel use; if fully electrifying, sends signal to downsize gas system.
Getting rid of your car:
WattTime — 5.17 mtCO/yr
Structural benefits: Supporting public transit and bike lanes, enabling others to use their cars less, too.
Switching from an omnivorous to a vegetarian diet:
WattTime and HowGood — 2.8 mtCO2/yr
Switching from an omnivorous to a vegan diet:
WattTime and HowGood — 2.9 mtCO2/yr
Replacing the beef in an omnivorous diet with chicken:
WattTime and HowGood — 2.5 mtCO2/yr
Structural benefits: Reduce demand for high-emitting food products, which has the double-pump benefit of reducing the amount of land required to cultivate high-emitting products; if replacing beef with chicken, increase demand for more carbon-efficient proteins; add to the business case for developing efficient plant-based proteins.
Cutting food waste in half:
WattTime and ReFED — more than 0.1 mtCO2/yr
Structural benefits: Reduce demand across the food system; send less food waste to landfill, which helps reduce methane emissions.
Composting all food waste:
WattTime and ReFED — 0.03 mtCO2/yr
Structural benefits: Encourages the build-out of municipal composting programs; encourages responsible farming practices by lowering the cost of compost; reduces demand for nitrogen-based fertilizer.
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Current conditions: More than 200 damaging wind reports from Missouri to Indiana came in so far this week as a series of storms wraps up over the Central United States • South Sudan’s capital of Juba is roasting in temperatures nearing 100 degrees Fahrenheit as heavy storms threaten to add to existing floods • Gale warnings are in effect in the Philippine Sea and the South China Sea as a northeasterly monsoon churns up winds of up to 40 knots.
And then there were three. Last month, Dominion Energy’s Coastal Virginia Offshore Wind started generating electricity for the mid-Atlantic grid just days after Orsted’s Revolution Wind entered into service off the coast of Rhode Island. Now a third U.S. offshore wind project is fully up and running. On Monday, Massachusetts Governor Maura Healey announced that Vineyard Wind had activated its electricity contracts with utilities, setting fixed prices for the 800-megawatt project 15 miles south of Martha’s Vineyard and Nantucket over the next 20 years. In a press release, Healey said the power purchase agreements will save Massachusetts ratepayers roughly $1.4 billion in electricity costs throughout these next two decades. “Throughout one of the coldest winters in recent history, Vineyard Wind turbines powered our homes and businesses at a low price and now that price goes even lower with the activation of these contracts,” Healey said in a statement. “Especially as President Trump is taking energy sources off the table and increasing prices with his war in Iran, we should be leaning into more American-made wind power.” Vineyard Wind first began selling power to the market in 2024, but at what The New Bedford Light called “fluctuating and at times higher prices.” As of this week and for the next year, the price will be set at $69.50 per megawatt-hour.
That hasn’t stopped the Trump administration from finding new ways to terminate other offshore wind projects. As I wrote yesterday, the Department of the Interior announced that two more projects — Bluepoint Wind off the coast of New Jersey and Golden State Wind off California — had taken the administration up on its offer to pay back the leasing costs up to a combined nearly $900 million in exchange for the developers abandoning the bids and agreeing not to pursue other offshore wind deals in the U.S. “We did not take this decision lightly,” Michael Brown, the CEO of Ocean Winds North America, told Heatmap’s Emily Pontecorvo in an emailed statement. “But when the underlying conditions in a market change, we must adapt. In this case, receiving a refund for the lease payments we had invested and exiting on agreed terms was the right outcome for our shareholders and partners.”
The United Arab Emirates said Tuesday it would withdraw from the Organization of the Petroleum Exporting Countries, shrinking the world’s biggest oil-producing cartel to just 11 nations. The decision takes effect on May 1. The announcement came ahead of Wednesday’s latest OPEC meeting in Vienna. Abu Dhabi said it will also quit the broader OPEC+ supergroup that includes non-members led by Russia. In a post on X, Sultan Al Jaber — who serves as the UAE’s minister of industry and advanced technology, the chief executive of the Abu Dhabi National Oil Company, and the chairman the country’s leading clean energy firm Masdar — said his nation had “taken a sovereign decision in line with its long-term energy strategy, its true production capability, and its national interest.” The National, Abu Dhabi’s state-owned English-language newspaper, wrote that “independence from OPEC will give the UAE, which accounts for roughly 4% of global oil production, more flexibility and responsiveness in managing the oil market.”
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The Interior Department’s Bureau of Land Management has issued a new categorical exclusion for geothermal, freeing developers from the requirement to carry out environmental reviews at yet another key step in the drilling process. The regulatory change marks the third new categorical exclusion for geothermal issued in the past two years. That comes after what Joel Edwards, the co-founder of the geothermal startup Zanskar, said in a post on X was a period of about 20 years “without any new” exclusions. In April 2024, pre-leasing and surveying got a categorical exclusion. In January 2025, a new categorical exclusion covered postleasing, drilling, and flow-testing on areas of up to 20 acres. Now this latest step will allow for an exemption on pre-leasing activities such as drilling up to 10 acres. “Very nice to see the agency continuing to streamline permitting,” Edwards wrote. “Still more bottlenecks to work out, but we’re moving in the right direction.”
On Tuesday, meanwhile, Senators Catherine Cortez Masto, a Democrat from Nevada, and Lisa Murkowski, a Republican from Alaska, introduced legislation to boost federal funding for next-generation geothermal research, development, and commercialization. “The U.S. is at the forefront of geothermal energy innovation, and this bill has the potential to strengthen global leadership, boost competitiveness, and accelerate the next generation of clean firm technologies,” Terra Rogers, director for superhot rock energy at Clean Air Task Force, said in a statement. “This nation has vast, underutilized next-generation geothermal and superhot rock potential.”
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CATL, the world’s largest battery market, has signed the world’s largest-ever order for sodium-ion batteries, the technology widely discussed as a potentially cheaper and more abundant alternative to the lithium power packs that propel electric vehicles and increasingly back up the grid. The Chinese giant inked a deal for 60 gigawatt-hours of batteries with the energy storage integrator HyperStrong. The deal marks what CATL calls proof that it has “overcome the challenges of the entire sodium-ion battery mass production chains,” prompting some experts to describe the agreement to Electrek as a potential “DeepSeek moment,” a reference to the Chinese artificial intelligence model that shook up the global industry with its affordability and nimbleness.
Sodium-ion batteries have seemed like the “next big thing” for years now, but as Heatmap’s Katie Brigham has reported, the industry has faced something of a curse when it comes to manufacturing, though new startups are attempting to overcome that problem.

Fuel loading has begun at Bangladesh’s first nuclear power station. The uranium rods could be in place in the Rooppur Nuclear Power Plant, made up of two VVER-1200 reactors designed and built by Russia’s state-owned Rosatom, in as little as 45 days. The plant will vault Bangladesh into the group of 31 nations that harness the power of splitting atoms for electricity production. “Today, Bangladesh joined the club of countries using peaceful nuclear energy as a reliable source of sustainable development,” Rosatom Director General Alexei Likhachev said in a statement to World Nuclear News. “The Rooppur Nuclear Power Plant will undoubtedly become a vital element of the country's energy system. For Rosatom, this project is another important step in the development of global nuclear energy and in strengthening friendly relations with our international partners.” When the plant generates its first power for the grid later this year, it will complete a project first planned when the country was known as East Pakistan.
When my high school girlfriend made my first Facebook account, I never imagined that, about 20 years later, the social network’s parent company would be trying to harvest electricity for its servers from outer space. But this week, Meta announced a deal with the startup Overview Energy, which aims to beam light from thousands of satellites to solar farms that power data centers at night, effectively making solar a 24-hour power source. Overview CEO Marc Berte said the goal is to launch the satellites by 2030, with what TechCrunch called “a goal of flying 1,000 spacecraft in geosynchronous orbit, a high orbit in which each satellite remains fixed above the same point on Earth.”
There are at least two more developers in a position to trade offshore leases for fossil fuel investment.
The Trump administration inked two more agreements to cancel offshore wind leases and reimburse the former leaseholders nearly $1 billion on Monday, demonstrating that its previous deals with TotalEnergies was not a one-off legal settlement but rather a new, repeatable strategy to throttle the industry.
Just like the deal with Total, the Interior Department is painting the agreement as a quid pro quo, where the companies will be reimbursed only after they invest an equivalent amount of money into U.S. oil and gas projects. There are a handful of remaining companies sitting on undeveloped offshore wind leases that could conceivably make similar deals. If they do, the cost to taxpayers could exceed $4 billion.
This latest deal will cancel leases for two projects, known as Bluepoint Wind and Golden State Wind. Bluepoint, a project off the coast of New York and New Jersey, was a joint venture between Global Infrastructure Partners, an investment firm owned by asset manager BlackRock, and Ocean Winds, which itself is a joint venture between the French energy company Engie and the developer EDP Renewables. The companies initially paid $765 million to acquire the lease.
The Interior Department announcement states that Global Infrastructure Partners has committed to investing that amount into an unspecified U.S. liquified natural gas facility. The firm is already a major investor in several U.S. LNG projects; alongside TotalEnergies, it reached a final investment decision last September for the expansion of the Rio Grande export terminal. If the lease cancellation agreement resembles the one struck with Total, as the Interior Department’s announcement suggests, Global Infrastructure Partners will be able to count this existing investment toward its total.
Golden State, one of the first leases sold off the Pacific coast, was a joint venture between Ocean Winds and the Canada Pension Plan Investment Board, an investment firm. The companies purchased it for $120 million. The government’s announcement is less specific about who will invest that money into what, noting only that it will be paid back after “an investment has been made of an equal amount in the development of U.S. oil and gas assets, energy infrastructure, and/or LNG projects along the Gulf Coast.” The Canada Pension Plan Investment Board has multiple investments in oil and natural gas pipelines and productions throughout the U.S. While Engie buys LNG from the U.S., the company has generally not been involved in U.S. oil and gas projects. EDP Renewables focuses solely on renewable energy and its parent company, EDP Group, is a Portuguese utility.
The government’s leasing laws generally do not allow companies to walk away from their lease and receive a refund. The government can cancel leases if it determines development would harm the environment or threaten national security — two claims the Trump administration has made — but only after holding a hearing on the matter.
The Trump administration has engineered a different route. In the same vein as the TotalEnergies deal, it has reached legal settlements with the companies and intends to pay them out of the Judgment Fund, a reserve overseen by the Department of Justice that agencies can draw from to pay for settlements arising from litigation or imminent litigation.
“We did not take this decision lightly,” Michael Brown, the CEO of Ocean Winds North America, told me in an emailed statement. “But when the underlying conditions in a market change, we must adapt. In this case, receiving a refund for the lease payments we had invested and exiting on agreed terms was the right outcome for our shareholders and partners.”
As I’ve reported previously, some legal experts are dubious that the circumstances constitute a legitimate use of the Judgment Fund. The agreement with Total was predicated on a series of “what if” scenarios — the Trump administration says it would have paused the company’s projects, which would have led Total to sue for breach of contract. Neither party actually did those things, instead negotiating these tit-for-tat trades with Trump.
Legal experts told me the only parties with the legal standing and the financial means to challenge the agreements are the states. I contacted the attorneys general offices in New York and New Jersey, which declined to comment, and California, which did not reply to my inquiry.
There are at least two remaining offshore wind developers who would be in a position to angle for a similar payout. RWE, a German energy company, paid $1.1 billion in 2022 to purchase a lease off the coast of New York and New Jersey for a project called Community Offshore — the most any company has paid to date for U.S. offshore wind development rights.
RWE, which previously focused its U.S. business on renewable energy, announced in March that it was developing 15 natural gas peaker plants in the U.S. In addition to Community Offshore, the company also bought rights to a lease in the Pacific for $121 million, and another in the Gulf of Mexico for about $4 million. The company did not respond to a request for comment, but its CEO has publicly suggested that it would be interested in getting its money back.
Another potential seller is Invenergy, which purchased a lease off the coast of New York and New Jersey in 2022 for $645 million for its Leading Light project. It also holds the rights to a Pacific lease bought for $112 million, and two in the Gulf of Maine, for which it paid about $9 million. The company is actively expanding its natural gas power plant fleet in the U.S. Invenergy declined to comment for this story.
The remaining companies that might be eligible for such deals paid much less for their offshore wind leases — BP, for example, paid just $135 million to obtain the lease for its Beacon Wind project in the Northeast. Duke Energy paid $130 million for a lease near North Carolina. BP’s offshore wind arm, JERA Nex bp, declined to comment on whether it would be amenable to a deal. Duke did not respond to my inquiry.
A company called EDF, a U.S. subsidiary of the French state-owned utility EDF Group, is sitting on a hefty $780 million lease, but the company is a renewables developer. There are no indications that its parent company is interested in expanding its natural gas pipeline in the U.S.
While Equinor and Dominion both have fossil fuel projects in the U.S., it seems unlikely they would reach similar deals for their remaining leases, given that they have already sued the Trump administration for halting work on offshore wind projects that were already under construction — Equinor’s Empire Wind and Dominion’s Coastal Virginia Offshore project.
Notably, Ocean Winds still has one remaining lease after this week’s deal, which it purchased on its own — not as a joint venture — in 2018, under the first Trump administration. Its SouthCoast Wind project off the coast of Massachusetts has nearly all of its approvals, though Trump’s Day One moratorium on offshore wind permits delayed construction. A subsequent lawsuit in March of last year from the city and county of Nantucket challenged the project’s Construction and Operations permit, typically the final federal approval for offshore wind farms. A federal judge ordered the permit to be sent back to the Bureau of Ocean Energy Management for reconsideration last fall; according to court filings, that process is ongoing.
If RWE, Invenergy, Duke, and BP each reached similar deals with the Trump administration, that would mean a total of just over $4 billion paid out of the Judgment Fund to cancel offshore wind leases, including the four existing deals. For context, the total amount the government paid to parties out of the Judgment Fund across all federal agencies in 2025 was about $4.4 billion, according to Treasury data. Annual totals over the last decade range between $1.7 billion in 2017 and $8.4 billion in 2020.
Party orthodoxy is no longer serving the energy transition, the Breakthrough Institute’s Seaver Wang and Peter Cook write.
President Trump has announced a dizzying array of executive branch led critical mineral policies since taking office again last year. While bombastically branded as new achievements, many elements from critical mineral tariffs to strategic stockpiling to Defense Production Act financing trace back to bipartisan recommendations and programs spanning the past several administrations.
Many Democrats in Congress, however, are stuck on the defensive. During a recent House Natural Resources hearing, for instance, Washington Representative Yassamin Ansari singled out the SECURE Minerals Act, a bipartisan proposal for a strategic minerals reserve, as “a framework ripe for fraud, corruption, and abuse.” Yet the draft bill actually contains strong safeguards: Senate confirmation of board members, annual independent audits, public tracking and annual reporting to Congress, conflict-of-interest prohibitions, and more.
In another House oversight hearing considering the reauthorization of the Export-Import Bank, California’s Maxine Waters expressed concern over President Trump’s mere contact with mineral producing countries in Africa, asking simply, “What is he doing?” The President of EXIM responded by reminding Waters of the bank’s charter to engage in sub-Saharan Africa.
In both cases, distrust of the administration and Republican lawmakers seems to have blinded Democrats to a larger strategic goal: building a secure critical mineral supply chain. Democrats who want to strengthen U.S. economic competitiveness and cultivate domestic clean technology sectors cannot afford to engage in partisan posturing at the expense of real policymaking. Nor can they afford to waste time — America’s vulnerabilities loom too large to wait until Trump leaves the White House.
Doing so will require Democrats to embrace certain positions that are at odds with recent party orthodoxy. First, they must accept the basic math that both the U.S. and the world will need new mine production and support incentives and regulatory reform for new critical minerals projects, not just recycling, re-mining, and substitution. And second, they must admit that mining projects in the U.S. and in democratically-governed partner countries offer a far better foundation for achieving high environmental and social standards than the currently dominant production routes for many raw materials today.
A recent hearing question from Texas Representative Christian Menefee hints at the risks of overly narrow minerals policy: “Should byproduct recovery be the first priority before we open up a single new mine?" While advocacy organizations and academic researchers have lately argued that operating mines dig up enough minerals to meet U.S. needs yet are currently neglecting to recover them, such analyses only consider the theoretical potential of extracting every element present in mined rock, not technical feasibility. Feasible recovery will be the exception, not the rule. Efforts to produce lithium as a byproduct from a copper-gold deposit might confront concentrations of under 20 parts per million, relative to concentrations at U.S. lithium mines currently under development that range from around 850 to 2,000 parts per million. Compared to cobalt concentrations of 2,400 parts per million at the Jervois Idaho Cobalt mine, Alaska’s large Red Dog zinc mine might boast 39 to 149 parts per million. For many elements, recovery would require new, first-of-a-kind extraction equipment consuming added water, energy, and chemical reagents — akin to burning a barn to fry an egg.
Recycling, too, is a meaningful category of solutions but ultimately limited. For instance, improved batteries and solar panels with longer service lives delay the point at which significant flows of materials become available for recycling. An increasing number of batteries and solar modules may also be redirected towards second-life use markets — electric vehicle batteries repurposed as electric grid storage assets, for example — diverting even more materials from recycling facilities.
To put such constraints into numbers, growing grid storage battery cell manufacturing capacity in the U.S. may surpass 96 gigawatt-hours by the end of this year, requiring over 17,000 tons of lithium content — alone equivalent to half of all worldwide lithium consumption in 2015. China’s tightening of rare earth export restrictions last year forced one of Ford’s auto plants to pause operations, and the shift to electric vehicles will only drive U.S. rare earths demand higher. The U.S. alone produced around 1 million EVs last year, relative to total auto manufacturing of 12 million to 14 million vehicles per year.
Even modest domestic manufacturing goals of 10 gigawatts of wind turbines and 2 million electric vehicles per year would require at least 100 tons of dysprosium and praseodymium, heavy rare earth elements that the U.S. is only just beginning to produce from recycling efforts and its sole operating mine. Globally, the International Energy Agency estimates that successful recycling expansion could avert around 5% to 30% of new mining activity, depending on the commodity.
The math is unforgiving. We need more minerals, and we need them soon.
For years, progressives have critiqued current U.S. mining regulations as antiquated and inadequate, insisting that standards governing existing mines expose marginalized communities to unacceptable impacts. While understandably reflecting past harms inflicted by mining prior to the enactment of stronger laws and regulations in the 1970s and 1980s, such a position exposes lawmakers to an uncomfortable contradiction: If modern mining and refining are structurally problematic industries, then not only must U.S. lawmakers advocate for improved industry standards domestically, logic dictates that they also use trade policies and international frameworks to penalize the unjust economic advantages benefiting irresponsible producers globally. The sum total of such actions might well slow the country’s transition to clean energy as opposed to speeding it.
Activist narratives that U.S. mining regulations offer the mining industry a smash-and-grab free-for-all obviously conflict with the reality that domestic mining has long been viewed as borderline uninvestible, with the U.S. seeing a 70% decrease in the number of active metal mines over the last 40 years. Insisting that more public engagement, extracting higher royalties to fund community projects, and quartering off certain areas with mineral potential for conservation will speed U.S. mining projects by neutralizing community opposition must consider how such high-cost projects can survive in a global market. China produces 10 times more graphite, rare earths, and polysilicon than the next largest producing country — and not by excelling at public engagement and community benefits-sharing. Continuing to indulge such domestic-only remonstrations will solve none of the nation’s supply challenges.
Meanwhile, efforts by both the Trump and Biden administrations are already driving progress towards improved recycling and utilization of unconventional wastes and resources. Biden’s Infrastructure Investment and Jobs Act funded numerous programs to produce new critical minerals without new mining, including Department of Energy grants to equip operating facilities with byproduct recovery systems, new mapping programs from the United States Geological Survey to locate historic mines with viable levels of critical minerals in abandoned wastes, and a Rare Earth Elements Demonstration Facility program at the Department of Energy to prioritize the use of waste as a feedstock. The Trump administration has continued to issue notices for IIJA-funded, waste resource, and recycling-focused opportunities into 2026. In short, maximization of byproduct potential, recycling, and remining is already established bipartisan policy.
Above all, Democrats must capitalize on the chance to start alleviating national critical mineral constraints now, in the middle of a Trump presidency, to position the U.S. industrial base to produce impressive economic and technological results in 2028 and beyond. Trump will depart the Oval Office in less than three years, whereas U.S. critical minerals strategy must play out over the next five to 10. Passing up promising opportunities today in the name of scoring short-term political points serves neither the nation’s best interests nor those of the Democratic Party.
Over the next two years, critical minerals policy offers rare bipartisan opportunities to supercharge innovation and build projects that will not only produce strategic materials but also solutions for cleaner industrial processes. In most cases, new U.S. production will already be less carbon-intensive than the global average. Meanwhile, federal policy support will foster U.S. process engineering know-how that might ultimately drive long-term breakthroughs in transformative cleaner solutions.
All of that said, policymakers must also balance environmental and innovation ambitions against realistic expectations and resist the temptation to chase only fully clean projects. For now, truly zero-carbon metals produced using green hydrogen or other novel techniques remain dramatically more expensive than metals produced with the most cost-efficient mix of energy inputs and feedstocks. Depending on the sector, domestic industries that have first achieved scale and rebuilt domestic expertise may position America better for catalyzing such shifts.
Cost competitive industries, after all, are also key for advancing Democratic priorities. More favorable costs for U.S.-produced critical materials and increasingly secure upstream secure supply chains will help make U.S.-manufactured technologies such as electric vehicles, solar modules, and electrolyzers more competitive. Responsible production capacity that is operating at scale will increase bargaining power for pressuring irresponsible producers overseas to reform, while creating new markets for American raw materials among principled partners and corporate offtakers.
Miners and metallurgists deserve an equal place of honor in the energy transition economy alongside rooftop solar installers and electricians, and such heavy industry workers can help rebuild a stronger U.S. labor movement.
But the risk of squandering such long-term opportunities is real. During the Biden administration, progressives reflexively fielded proposals that would add regulatory burdens and make mining more difficult — proposals which largely went nowhere. Meanwhile, the bipartisan Mining Regulatory Clarity Act — one of the few specific regulatory reforms proposed for the mining sector to date — still has not passed since its introduction in 2023. The current version is stalled over the inclusion of provisions that would redirect mining administrative fees to cleaning up abandoned mines. Remediating legacy sites is an important federal government obligation, but the quid pro quo calculus of extracting concessions for simple regulatory reforms both complicates their passage while also procrastinating standalone measures to address abandoned mines.
Certainly, the current political moment could not be more charged. Another recent House Natural Resources hearing on oversight ended abruptly after Oregon Representative Maxine Dexter moved to subpoena Donald Trump, Jr. over concerns that administration financial support favored mineral companies in which he was invested. This episode highlights the challenge for Democrats — holding the federal government accountable to the U.S. public while simultaneously working to address the country’s critical mineral priorities.
This is less complicated than it sounds. Lawmakers on both sides of the aisle can agree on strong oversight provisions to ensure that programs prioritize the nation’s interests and achieve political longevity. Democrats should therefore lean in to their desired guardrails, be they mandatory public transparency, reviews of company history and project feasibility, or conflict-of-interest restrictions. Stronger congressional oversight and robust environmental and human rights safeguards are worthy Democratic goals, but advancing them requires that Congress do its job and legislate.