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As heat waves get worse, these fixes will help keep your home cool and energy efficient.

July 2023 will almost certainly be declared the hottest month ever recorded, but it is unlikely to hold that record for long. Climate change is making heat waves more frequent, intense, and longer-lasting across the U.S.
Adapting to this hotter future is often discussed at the scale of a city; measured in early warning systems, green spaces, and cooling centers. But there’s also a lot that individual homeowners can do to help their communities and protect themselves.
While the vast majority of American households — some 88% — use air conditioning for relief, homeowners would be wise to consider a variety of additional, “passive” cooling techniques. These are strategies that can keep your home at a safe temperature during a heat wave if the power goes out, an increasingly likely scenario. They will also save you a bit of money on energy bills. In a sense, adapting your home to extreme heat is just another way of thinking about how to make it more energy efficient.
These retrofits also have wider benefits. Since air conditioners work by transferring heat from inside your house outdoors, these fixes can cool down your neighborhood. They’ll cut carbon emissions and air pollution by lowering demand for electricity. If widely adopted, they’ll also help prevent blackouts and could shrink the amount of renewable energy projects that need to be built to replace fossil fuels, alleviating pressure on conservation.
I spoke with Steve Easley, a building science consultant who specializes in energy efficiency, and Shawn Maurer, technical director of the Smart Energy Design Assistance Center at the University of Illinois, about how homeowners should prioritize their options when it comes to passive cooling.
“I always recommend that people do a home energy audit from a certified HERS rater,” Easley told me, referring to the Home Energy Rating System, a nationally recognized system for inspecting and calculating a home’s energy performance. The auditor will tell you how leaky your house is, and how well your roof insulation, windows, and other parts of your house are working to keep out heat, and help you figure out what to attack first. (Easley also recommends getting at least three quotes for any of these solutions, because different contractors bid this work out very differently.)
Below are five things you can do to improve your home’s resilience to heat. Depending on a number of factors — such as where you live, how your house is constructed, and the condition it's in — the mileage you can get out of each of these measures will vary. The good news is that the federal government and many state governments offer tax credits and rebates for most of these solutions. The Inflation Reduction Act created the Energy Efficient Home Improvement tax credit, which offers homeowners up to $1,200 per year to spend on energy efficiency improvements. As part of that, you can claim $150 simply for getting an energy audit.
Maurer said the very first thing he would do to improve the efficiency of a home is to seal up any cracks where air can get in — for example, along the edges of the floors, around the windows, and in the ceiling around light fixtures. “That carries in moisture, heat, and everything from outdoors into the house. It's going to offset any air conditioned air you got inside the house. So air leakage is usually the place we recommend to start,” he said. “And then from there, it's what your budget can handle as far as adding more insulation to your house.”
Insulation comes in a wide range of materials, such as fiberglass and rock wool, blown cellulose, and rigid foam boards. It can be blown into your walls, installed on the floor of the attic, or underneath your roof deck. It’s a jack-of-all-trades when it comes to energy efficiency, since it keeps heat inside in the winter and blocks it from entering in the summer. That means it’s a great option for those in colder climates that also want to prepare their homes for hotter summers.
A 2021 study by a group of researchers at Lawrence Berkeley National Lab modeled the efficacy of a wide array of passive cooling measures in low-income homes in Fresno, California. It found that roof insulation, along with solar-control window films, which we’ll get to in a moment, were the two most effective ways to keep heat from entering the buildings. However, the authors note that roof insulation is an expensive major retrofit, and recommend that it only be done when the roof needs replacement.
A good first step might be finding out what kind of insulation you already have. The most important metric when it comes to insulation is called “R-value,” and the higher the number, the more effective it is. Older homes may have attic insulation as low as R-13, whereas modern building codes typically require insulation between R-38 and R-60.
The new federal tax credit offers up to 30% of the total cost of a project for air sealing and insulation, maxing out at $1,200 total. (Labor costs are not covered by the credit.)
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Having a light-colored roof and exterior will most certainly keep your home cooler than darker options, but not all light colors are created equal. “Cool” roofs and walls are made with special materials that reflect solar energy back into space, preventing it from being absorbed by the building. They also have high “thermal emittance,” meaning they release a lot of the heat that they do absorb, rather than sending it indoors.
All kinds of materials have been developed with these properties. For roofs, there are tiles, shingles, membranes, liquid coatings, and products made of slate, wood, and metal.
Cool roofs don’t necessarily have to be white, although the color does work very well. According to a database maintained by the Cool Roof Ratings Council, the most effective products tend to be bright white coatings, but there are also gray, green, blue, brown, and tan products that are rated highly.
For reflective walls, the most effective products similarly come in white and other light-colored paints, which can reflect 60 to 90 percent of sunlight when new. An extensive 2019 study of reflective wall paints by the same group at Lawrence Berkeley National Lab found that cool walls can reduce annual energy use in single-family homes in warmer U.S. climates by 2% to 8.5%.
Easley said it’s worth considering a cool roof if you have a central air conditioning system in your attic. Otherwise, attics in places like Arizona can get upwards of 130 degrees, taxing the equipment and forcing it to work harder. If your attic isn’t home to your AC, it may only make financial sense to do this kind of retrofit if your house is already in need of a new paint job or your roof needs work.
But it’s probably not worth considering a cool roof if you live in a colder climate, like the Northeast and upper Midwest, since cool roofs can actually make it colder inside in the winter.
There’s no federal incentives for cool roofs, but several states and utilities offer rebates.
This is a big category, and it’s easy to get overwhelmed by the options. Starting with those that will likely cost the most to the least, you can:
• Replace your windows altogether.
• Add storm windows to the interior or exterior of your existing glass.
• Purchase films that can be applied to the existing glass to increase its reflectivity.
• Install external shutters or awnings that block the sun.
• Install interior blinds and curtains that block the sun.
Here’s a rundown of each option.
New windows: Replacing your windows can cost tens of thousands of dollars, so unless they are already in need of repair, you may want to hold off on that option. But when the day does come around, you’ll want to look for “Low-E” windows, which stands for low emissivity. The inside of the glass is coated with microscopic layers of silver that reflect heat while still allowing light to pass through.
Within that category, you’ll also want to look for windows that have what’s called a low “solar heat gain coefficient.” This measures how much heat is absorbed by the glass and transferred inside. It’s rated on a scale of 0 to 1. If you live somewhere that’s sunny year round like Arizona, you ideally want one rated 0.25 or lower.
Through 2032, homeowners can claim up to $600 in federal tax credits for purchasing Energy Star rated windows.
Storm windows: Rather than replacing your windows entirely, it’s far cheaper to install storm windows with Low-E glass, which basically involves bolting another window to the outside of your house. Storm windows have an added benefit of improving air sealing, eliminating drafts.
Film: An even lower-cost option is to look into films with low solar heat gain coefficients that can be applied to existing windows. However, Easeley warned that many manufacturers will void your warranty if you add films to your windows.
Shutters, awnings, blinds, and curtains: Exterior shutters and overhangs that block the sun from ever reaching your windows will generally be more effective than interior shades or blinds, but all of these measures can help. “Window blinds and curtains are really dirt cheap ways to control energy,” said Maurer. “It’s not a very good buffer, but it’s something.”
The Berkeley study on passive cooling measures notes that blinds moderately improve how much heat from the sun enters your home, but they can feel more effective by reducing the sensation of sunlight streaming into your house.
If you still have any incandescent lights, they can also be a significant source of heat. They should be replaced with LED lights.
Planting trees, climbing ivy, and other vegetation can also passively cool your house by shading both your house and any surrounding pavement. However, if you have solar panels, or plan to get them in the future, do not plant trees on the south side of your home as it may reduce the solar system’s effectiveness.
Maurer cautioned that if you do a bunch of work in your home to reduce your cooling needs, you’ll want to keep that in mind if you ever have to replace your air conditioner. He advised having a contractor come in to re-measure what size system you need, since doing a like-for-like replacement will probably be overkill and could result in it malfunctioning.
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In practice, direct lithium extraction doesn’t quite make sense, but 2026 could its critical year.
Lithium isn’t like most minerals.
Unlike other battery metals such as nickel, cobalt, and manganese, which are mined from hard-rock ores using drills and explosives, the majority of the world’s lithium resources are found in underground reservoirs of extremely salty water, known as brine. And while hard-rock mining does play a major role in lithium extraction — the majority of the world’s actual production still comes from rocks — brine mining is usually significantly cheaper, and is thus highly attractive wherever it’s geographically feasible.
Reaching that brine and extracting that lithium — so integral to grid-scale energy storage and electric vehicles alike — is typically slow, inefficient, and environmentally taxing. This year, however, could represent a critical juncture for a novel process known as Direct Lithium Extraction, or DLE, which promises to be faster, cleaner, and capable of unlocking lithium across a wider range of geographies.
The traditional method of separating lithium from brine is straightforward but time-consuming. Essentially, the liquid is pumped through a series of vast, vividly colored solar evaporation ponds that gradually concentrate the mineral over the course of more than a year.
It works, but by the time the lithium is extracted, refined, and ready for market, both the demand and the price may have shifted significantly, as evidenced by the dramatic rise and collapse of lithium prices over the past five years. And while evaporation ponds are well-suited to the arid deserts of Chile and Argentina where they’re most common, the geology, brine chemistry, and climate of the U.S. regions with the best reserves are generally not amenable to this approach. Not to mention the ponds require a humongous land footprint, raising questions about land use and ecological degradation.
DLE forgoes these expansive pools, instead pulling lithium-rich brine into a processing unit, where some combination of chemicals, sorbents, or membranes isolate and extricate the lithium before the remaining brine gets injected back underground. This process can produce battery-grade lithium in a matter of hours or days, without the need to transport concentrated brine to separate processing facilities.
This tech has been studied for decades, but aside from a few Chinese producers using it in combination with evaporation ponds, it’s largely remained stuck in the research and development stage. Now, several DLE companies are looking to build their first commercial plants in 2026, aiming to prove that their methods can work at scale, no evaporation ponds needed.
“I do think this is the year where DLE starts getting more and more relevant,” Federico Gay, a principal lithium analyst at Benchmark Mineral Intelligence, told me.
Standard Lithium, in partnership with oil and gas major Equinor, aims to break ground this year on its first commercial facility in Arkansas’s lithium-rich Smackover Formation, while the startup Lilac Solution also plans to commence construction on a commercial plant at Utah’s Great Salt Lake. Mining giant Rio Tinto is progressing with plans to build a commercial DLE facility in Argentina, which is already home to one commercial DLE plant — the first outside of China. That facility is run by the French mining company Eramet, which plans to ramp production to full capacity this year.
If “prices are positive” for lithium, Gay said, he expects that the industry will also start to see mergers and acquisitions this year among technology providers and larger corporations such as mining giants or oil and gas majors, as “some of the big players will try locking in or buying technology to potentially produce from the resources they own.” Indeed, ExxonMobil and Occidental Petroleum are already developing DLE projects, while major automakers have invested, too.
But that looming question of lithium prices — and what it means for DLE’s viability — is no small thing. When EV and battery storage demand boomed at the start of the decade, lithium prices climbed roughly 10-fold through 2022 before plunging as producers aggressively ramped output, flooding the market just as EV demand cooled. And while prices have lately started to tick upward again, there’s no telling whether the trend will continue.
“Everyone seems to have settled on a consensus view that $20,000 a tonne is where the market’s really going to be unleashed,” Joe Arencibia, president of the DLE startup Summit Nanotech, told me, referring to the lithium extraction market in all of its forms — hard rock mining, traditional brine, and DLE. “As far as we’re concerned, a market with $14,000, $15,000 a tonne is fine and dandy for us.”
Lilac Solutions, the most prominent startup in the DLE space, expects that its initial Utah project — which will produce a relatively humble 5,000 metric tons of lithium per year — will be profitable even if lithium prices hit last year’s low of $8,300 per metric ton. That’s according to the company’s CEO Raef Sully, who also told me that because Utah’s reserves are much lower grade than South America’s, Lilac could produce lithium for a mere $3,000 to $3,500 in Chile if it scaled production to 15,000 or 20,000 metric tons per year.
What sets Lilac apart from other DLE projects is its approach to separating lithium from brine. Most companies are pursuing adsorption-based processes, in which lithium ions bind to an aluminum-based sorbent, which removes them from surrounding impurities. But stripping the lithium from the sorbent generally requires a good deal of freshwater, which is not ideal given that many lithium-rich regions are parched deserts.
Lilac’s tech relies on an ion-exchange process in which small ceramic beads selectively capture lithium ions from the brine in their crystalline structure, swapping them for hydrogen ions. “The crystal structure seems to have a really strong attraction to lithium and nothing else,” Sully told me. Acid then releases the concentrated lithium. When compared with adsorption-based tech, he explained, this method demands far fewer materials and is “much more selective for lithium ions versus other ions,” making the result purer and thus cheaper to process into a battery-grade material.
Because adsorption-based DLE is already operating commercially and ion-exchange isn’t, Lilac has much to prove with its first commercial facility, which is expected to finalize funding and begin construction by the middle of this year.
Sully estimates that Lilac will need to raise around $250 million to build its first commercial facility, which has already been delayed due to the price slump. The company’s former CEO and current CTO Dave Snydacker told me in 2023 that he expected to commence commercial operations by the end of 2024, whereas now the company plans to bring its Utah plant online at the end of 2027 or early 2028.
“Two years ago, with where the market was, nobody was going to look at that investment,” Sully explained, referring to its commercial plant. Investors, he said, were waiting to see what remained after the market bottomed out, which it now seems to have done. Lilac is still standing, and while there haven’t yet been any public announcements regarding project funding, Sully told me he’s confident that the money will come together in time to break ground in mid-2026.
It also doesn’t hurt that lithium prices have been on the rise for a few months, currently hovering around $20,000 per tonne. Gay thinks prices are likely to stabilize somewhere in this range, as stakeholders who have weathered the volatility now have a better understanding of the market.
At that price, hard rock mining would be a feasible option, though still more expensive than traditional evaporation ponds and far above what DLE producers are forecasting. And while some mines operated at a loss or mothballed their operations during the past few years, Gay thinks that even if prices stabilize, hard-rock mines will continue to be the dominant source of lithium for the foreseeable future due to sustained global investment across Africa, Brazil, Australia, and parts of Asia. The price may be steeper, but the infrastructure is also well-established and the economics are well-understood.
“I’m optimistic and bullish about DLE, but probably it won’t have the impact that it was thought about two or three years ago,” Gay told me, as the hype has died down and prices have cooled from their record high of around $80,000 per tonne. By 2040, Benchmark forecasts that DLE will make up 15% to 20% of the lithium market, with evaporation ponds continuing to be a larger contributor for the next decade or so, primarily due to the high upfront costs of DLE projects and the time required for them to reach economies of scale.
On average, Benchmark predicts that this tech will wind up in “the high end of the second quartile” of the cost curve, making DLE projects a lower mid-cost option. “So it’s good — not great, good. But we’ll have some DLE projects in the first quartile as well, so competing with very good evaporation assets,” Gay told me.
Unsurprisingly, the technology companies themselves are more bullish on their approach. Even though Arencibia predicts that evaporation ponds will continue to be about 25% cheaper, he thinks that “the majority of future brine projects will be DLE,” and that DLE will represent 25% or more of the future lithium market.
That forecast comes in large part because Chile — the world’s largest producer of lithium from brine — has stated in its National Lithium Strategy that all new projects should have an “obligatory requirement” to use novel, less ecologically disruptive production methods. Other nations with significant but yet-to-be exploited lithium brine resources, such as Bolivia, could follow suit.
Sully is even more optimistic, predicting that as lithium demand grows from about 1.5 million metric tons per year to around 3.5 million metric tons by 2035, the majority of that growth will come from DLE. “I honestly believe that there will be no more hard rock mines built in Australia or the U.S.,” he said, telling me that in ten years time, half of our lithium supply could “easily” come from DLE.
As a number of major projects break ground this year and the big players start consolidating, we’ll begin to get a sense of whose projections are most realistic. But it won’t be until some of these projects ramp up commercial production in the 2028 to 2030 timeframe that DLE’s market potential will really crystalize.
“If you’re not a very large player at the moment, I think it’s very difficult for you to proceed,” Sully told me, reflecting on how lithium’s price shocks have rocked the industry. Even with lithium prices ticking precariously upwards now, the industry is preparing for at least some level of continued volatility and uncertainty.
“Long term, who knows what [prices are] going to be,” Sully said. “I’ve given up trying to predict.”
A chat with CleanCapital founder Jon Powers.
This week’s conversation is with Jon Powers, founder of the investment firm CleanCapital. I reached out to Powers because I wanted to get a better understanding of how renewable energy investments were shifting one year into the Trump administration. What followed was a candid, detailed look inside the thinking of how the big money in cleantech actually views Trump’s war on renewable energy permitting.
The following conversation was lightly edited for clarity.
Alright, so let’s start off with a big question: How do investors in clean energy view Trump’s permitting freeze?
So, let’s take a step back. Look at the trend over the last decade. The industry’s boomed, manufacturing jobs are happening, the labor force has grown, investments are coming.
We [Clean Capital] are backed by infrastructure life insurance money. It’s money that wasn’t in this market 10 years ago. It’s there because these are long-term infrastructure assets. They see the opportunity. What are they looking for? Certainty. If somebody takes your life insurance money, and they invest it, they want to know it’s going to be there in 20 years in case they need to pay it out. These are really great assets – they’re paying for electricity, the panels hold up, etcetera.
With investors, the more you can manage that risk, the more capital there is out there and the better cost of capital there is for the project. If I was taking high cost private equity money to fund a project, you have to pay for the equipment and the cost of the financing. The more you can bring down the cost of financing – which has happened over the last decade – the cheaper the power can be on the back-end. You can use cheaper money to build.
Once you get that type of capital, you need certainty. That certainty had developed. The election of President Trump threw that into a little bit of disarray. We’re seeing that being implemented today, and they’re doing everything they can to throw wrenches into the growth of what we’ve been doing. They passed the bill affecting the tax credits, and the work they’re doing on permitting to slow roll projects, all of that uncertainty is damaging the projects and more importantly costs everyone down the road by raising the cost of electricity, in turn making projects more expensive in the first place. It’s not a nice recipe for people buying electricity.
But in September, I went to the RE+ conference in California – I thought that was going to be a funeral march but it wasn’t. People were saying, Now we have to shift and adjust. This is a huge industry. How do we get those adjustments and move forward?
Investors looked at it the same way. Yes, how will things like permitting affect the timeline of getting to build? But the fundamentals of supply and demand haven’t changed and in fact are working more in favor of us than before, so we’re figuring out where to invest on that potential. Also, yes federal is key, but state permitting is crucial. When you’re talking about distributed generation going out of a facility next to a data center, or a Wal-Mart, or an Amazon warehouse, that demand very much still exists and projects are being built in that middle market today.
What you’re seeing is a recalibration of risk among investors to understand where we put our money today. And we’re seeing some international money pulling back, and it all comes back to that concept of certainty.
To what extent does the international money moving out of the U.S. have to do with what Trump has done to offshore wind? Is that trade policy? Help us understand why that is happening.
I think it’s not trade policy, per se. Maybe that’s happening on the technology side. But what I’m talking about is money going into infrastructure and assets – for a couple of years, we were one of the hottest places to invest.
Think about a European pension fund who is taking money from a country in Europe and wanting to invest it somewhere they’ll get their money back. That type of capital has definitely been re-evaluating where they’ll put their money, and parallel, some of the larger utility players are starting to re-evaluate or even back out of projects because they’re concerned about questions around large-scale utility solar development, specifically.
Taking a step back to something else you said about federal permitting not being as crucial as state permitting–
That’s about the size of the project. Huge utility projects may still need federal approvals for transmission.
Okay. But when it comes to the trendline on community relations and social conflict, are we seeing renewable energy permitting risk increase in the U.S.? Decrease? Stay the same?
That has less to do with the administration but more of a well-structured fossil fuel campaign. Anti-climate, very dark money. I am not an expert on where the money comes from, but folks have tried to map that out. Now you’re even seeing local communities pass stuff like no energy storage [ordinances].
What’s interesting is that in those communities, we as an industry are not really present providing facts to counter this. That’s very frustrating for folks. We’re seeing these pass and honestly asking, Who was there?
Is the federal permitting freeze impacting investment too?
Definitely.
It’s not like you put money into a project all at once, right? It happens in these chunks. Let’s say there’s 10 steps for investing in a project. A little bit of money at step one, more money at step two, and it gradually gets more until you build the project. The middle area – permitting, getting approval from utilities – is really critical to the investments. So you’re seeing a little bit of a pause in when and how we make investments, because we sometimes don’t know if we’ll make it to, say, step six.
I actually think we’ll see the most impact from this in data center costs.
Can you explain that a bit more for me?
Look at northern Virginia for a second. There wasn’t a lot of new electricity added to that market but you all of the sudden upped demand for electricity by 20 percent. We’re literally seeing today all these utilities putting in rate hikes for consumers because it is literally a supply-demand question. If you can’t build new supply, it's going to be consumers paying for it, and even if you could build a new natural gas plant – at minimum that will happen four-to-six years from now. So over the next four years, we’ll see costs go up.
We’re building projects today that we invested in two years ago. That policy landscape we invested in two years ago hasn’t changed from what we invested into. But the policy landscape then changed dramatically.
If you wipe out half of what was coming in, there’s nothing backfilling that.
Plus more on the week’s biggest renewables fights.
Shelby County, Indiana – A large data center was rejected late Wednesday southeast of Indianapolis, as the takedown of a major Google campus last year continues to reverberate in the area.
Dane County, Wisconsin – Heading northwest, the QTS data center in DeForest we’ve been tracking is broiling into a major conflict, after activists uncovered controversial emails between the village’s president and the company.
White Pine County, Nevada – The Trump administration is finally moving a little bit of renewable energy infrastructure through the permitting process. Or at least, that’s what it looks like.
Mineral County, Nevada – Meanwhile, the BLM actually did approve a solar project on federal lands while we were gone: the Libra energy facility in southwest Nevada.
Hancock County, Ohio – Ohio’s legal system appears friendly for solar development right now, as another utility-scale project’s permits were upheld by the state Supreme Court.