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Why the grid of the future might hinge on these 10 projects.
The energy transition happens one project at a time. Cutting carbon emissions is not simply a matter of shutting down coal plants or switching to electric cars. It calls for a vast number of individual construction projects to coalesce into a whole new energy system, one that can generate, transmit, and distribute new forms of clean power. Even with the right architecture of regulations and subsidies in place, each project must still conquer a series of obstacles that can require years of planning, fundraising, andcajoling, followed by exhaustive review before they can begin building, let alone operating.
These 10 projects represent the spectrum of solutions that could enable a transition to a carbon-free energy system. The list includes vastly scaled up versions of mature technologies like wind and solar power alongside the traditional energy infrastructure necessary to move that power around. Many of the most experimental or first-of-a-kind projects on this list are competing to play the role of “clean firm” power on the grid of the future. Form’s batteries, Fervo’s geothermal plants, NET Power’s natural gas with carbon capture, and TerraPower’s molten salt nuclear reactor could each — in theory — dispatch power when it’s needed and run for as long as necessary, unconstrained by the weather. Others, like Project Cypress, are geared at solving more distant problems, like cleaning up the legacy carbon in the atmosphere.
But they do not all have a clear path to success. Each one has already faced challenges, and many of them are likely to face a great number more. We call these the make-or-break energy projects because it's still unclear what the clean energy system of the future is going to look like, but the projects from this list are likely to play a big part in it — if, that is, they get there.
Heatmap Illustration/Getty Images
Type of project: Solar farm
Developer: Intersect Power
Location: Desert Center, Riverside County, California.
Size: 400 megawatts of generation and 650 megawatts of storage
Operation date: Possibly 2025
Cost: $990 million
Why it matters: Facing opposition from local retirees angered by the large number of projects popping up in the area, as well as from conservation-focused groups — such as Basin and Range Watch, which opposes many utility-scale energy projects in desert areas — Easley will be a test of whether California’s reforms to limit the timeframe of appeals to the state’s environmental reviews can actually work in getting a project approved and online faster.
The early signs are promising. A nearby solar project by the same developer, Intersect Power, recently went into operation after getting approved by the Bureau of Land Management in January 2022. Easley could be operational “as early as late 2025,” according to a Plan of Development prepared for Intersect Power.
Easley is also an example of what’s increasingly becoming standard in California, at both the residential and utility-scale level: pairing solar with storage. The California grid increasingly relies on batteries to keep the lights on as solar ramps up and down in the mornings and, especially, the evenings. The state has procured a massive amount of storage and has adjusted how utilities pay for rooftop solar in a way that encourages pairing battery systems with rooftop solar panels. This both stabilizes the grid and helps further decarbonize it, as batteries that are physically close to intermittent renewables are more likely to abate carbon emissions.
Heatmap Illustration/Form Energy
Type: Energy storage
Developer: Form Energy and Great River Energy
Location: Cambridge, Minnesota
Size: 150 megawatt hours
Operation date: End of 2025
Cost: Unknown; Goal of less than 1/10th cost of utility-scale lithium-ion batteries per megawatt hour
Why it matters: Form Energy first made waves in 2020 when it announced a contract with Great River Energy, a Minnesota electric utility, to build a battery that could store 100 hours’ worth of electricity, which was simply unheard of. Other energy storage companies were just trying to break the 4-hour limitation of lithium-ion, aiming for 8 hours or, at most, 12. Days-long energy storage would be a game changer for maintaining reliability during extreme weather events, storing renewable energy for stretches of cloudy days or windless nights or kicking in when demand peaks. At first, Form’s project was shrouded in mystery. How, exactly, would it do this? But a year later, the company revealed the secret chemistry behind its breakthrough: iron and oxygen. The batteries are filled with iron pellets that, when exposed to oxygen, rust, releasing electrons to the grid. They “charge” by running in reverse, using the electrical current from the grid to convert the rust back to iron.
Since then, the hype has continued to build. Form has raised nearly $1 billion from venture capital and been awarded tens of millions more ingovernment grants. It has signed contracts with six utilities to deploy projects in California, New York, Virginia, Georgia, and Colorado, in addition to Minnesota. All this, despite not having completed a single project yet.
The Great River Energy Project is set to be the first to come online. Originally, the company said it would be operating by the end of 2023; now it’s expected to start construction later this year and begin operating in early 2025, Vice President of Communications Sarah Bray told Heatmap. First, the company has to complete construction of its first factory in Weirton, West Virginia, where it will be producing all of the batteries. Bray said it expects to start high-volume production later this year.
Heatmap Illustration/Getty Images
Type: Onshore wind
Developer: Pattern Energy
Location: Lincoln, Torrance, and San Miguel Counties, New Mexico, with transmission into Arizona
Size: 3,500 megawatts
Operation date: 2026
Cost: The project’s developer, Pattern Energy, has secured $11 billion in financing for the wind and associated transmission project. The cost of the project is estimated to be $8 billion.
Why it matters: This would be the biggest wind project in the country and a test case for a variety of energy policy objectives at both the state and federal level. For California, it would be a key step in decarbonizing its grid, as the state right now imports a large amount of its power, not all of which is carbon-free. For the federal government, it meets several goals — using public lands for carbon-free energy development, plus long-distance transmission to spur energy development across the country and link clean power resources in rural areas to major load centers.
It would also mean an ambitious project could overcome long and concerted opposition. The project was first proposed in 2006, and its transmission line cleared environmental review back in 2015, but it has been mired in lawsuit after lawsuit. Most recently, a coalition of conservation groups and Indian tribes sued to halt construction on the power line portion of the project in Arizona’s San Pedro Valley, claiming that their cultural rights had not been adequately respected. In April, a judge allowed construction to continue, ruling that those claims were barred by the existing federal approvals, which had taken years to attain.
Heatmap Illustration/Getty Images
Type: Offshore wind
Developer: Equinor
Location: South of Long Island, New York
Size: 810 megawatts
Operation date: 2026
Cost: Not available, but an earlier estimate for developing two wind farms was $3 billion. Costs have since risen, but the second farm, Empire Wind 2, is no longer under contract.
Why it matters: The Northeast, and especially New York State, have aggressive aims for decarbonization, with a goal of 70% of the state’s electricity coming from renewables by 2030. The Biden administration also has a specific goal for 30 gigawatts of offshore wind capacity by 2030, and New York has a goal of 9 gigawatts by 2035. These types of high-capacity projects will be essential for the Northeast to decarbonize. The windy coast of the Atlantic Ocean is the most potent large-scale renewable resource in the region, and many of the region’s large load centers, such as New York City and Boston, are on the coast.
Offshore wind, while expensive, can present less permitting hassle and local opposition than onshore wind or utility-scale solar. Empire Wind 1 (along with Sunrise Wind) matters tremendously for New York’s offshore wind program, which has been in development for years but has faced escalating costs and project cancellations. Only one offshore wind project is actually operational in the state, South Fork Wind, which was contracted outside the NYSERDA process and has around 130 megawatts of capacity. If Empire manages to get steel in the water and electrons flowing to the coast, it will be a sign that the Northeast’s — and thus the country’s — decarbonization goals are at least somewhat attainable.
Heatmap Illustration/Getty Images
Type: Transmission
Developers: Transmission Developers, which is owned by the Blackstone Group
Size: 339 miles / 1,250 megawatts
Operation date: 2026
Cost: $6 billion
Why it matters: The Champlain Hudson Power Express, often referred to as CHPE (affectionately pronounced “chippy”) will deliver 1,250 megawatts of hydropower from Quebec into the New York City grid, which is currently about 90% powered by fossil fuels. It is “the most powerful project you’ll never see,” according to its developers, as it is the largest transmission line in the country to be installed entirely underground and underwater.
The project is essential to New York’s goal to build a zero-emission electricity system by 2040. The line will supply an always-available source of clean power to supplement intermittent wind and solar generation and maintain a reliable grid. It has already overcome a number of barriers, including nearly a decade of environmental reviews, uncertainty over whether New York would buy its power, and opposition from conservation advocates concerned about the negative impacts of hydroelectric dams on the environment and on Native communities in Canada.
When it begins operating, New Yorkers won’t just get cleaner power — they should also see air quality benefits almost immediately. The new line is expected to cut air pollution equivalent to that released by 15 of the city’s 16 fossil fuel-fired peaker plants.
Heatmap Illustration/Fervo
Developer: Fervo
Type: Geothermal
Location: Beaver County, Utah
Size: 400 megawatts
Operation date: 2026, although the project isn’t expected to be finished until 2028
Cost: Not disclosed, but Fervo raised $244 million and said that the cash “will support Fervo’s continued operations at Cape Station.”
Why it matters: This enhanced geothermal project is not the first one for Fervo. The company’s Nevada site, Project Red, began providing power for Google data centers in Nevada in November 2023. This planned site, however, will be far bigger: Fervo currently has authorization from the Bureau of Land Management for up to 29 exploratory wells, while the Project Red site had just two. Cape Station broke ground in September 2023, and in the first six months of drilling, Fervo said it reduced costs from drilling by 70% compared to its Project Red wells.
As the grid decarbonizes and major power consumers like technology companies insist on having clean power for their operations, there will be massive and growing demand for so-called “clean firm” power, carbon-free power that is available all the time. Conventional wind and solar is intermittent, and existing battery technology only allows for limited output over time. Fervo’s “enhanced geothermal” technology uses techniques borrowed from the oil and gas industry to be able to produce geothermal power essentially anywhere where there are hot enough rocks underneath the surface of the Earth, as opposed to conventional geothermal, which depends on locating hot enough fluid or stream.
If Fervo can demonstrate that it can produce power at scale at costs comparable to existing conventional geothermal projects, it can expect a massive market for it and demand for more projects.
Heatmap Illustration/TerraPower
Type: Nuclear
Developer: TerraPower
Location: Kemmerrer, Wyoming
Size: 345 megawatts
Operation date: Not available, but the company said in 2021 that it plans to be operational “in the next seven years.” Updated to the 2024 application, that would put it on track for a 2030 completion date.
Cost: Not available, but TerraPower has raised around $1 billion and the federal government has pledged around $2 billion to support the project, which TerraPower has said it will “match … dollar for dollar.”
Why it matters: TerraPower is just one of many companies flogging designs for advanced nuclear reactors, which are smaller and promise to be cheaper to build than America’s existing light-water nuclear reactor fleet. The construction permit application the company submitted in March was a first for a commercial advanced reactor. TerraPower matters as much for the Nuclear Regulatory Commission as it does for anyone else, as it’s a test of whether the NRC can meet Congress and the White House’s preference for a more accelerated approval process for advanced nuclear power.
TerraPower’s design, if successful, would be a landmark for the American nuclear industry. The reactor design calls for cooling with liquid sodium instead of the standard water-cooling of American nuclear plants. This technique promises eventual lower construction costs because it requires less pressure than water (meaning less need for expensive safety systems) and can also store heat, turning the reactor into both a generator and an energy storage system.
While there are a number of existing advanced nuclear designs, several of which involve liquid sodium, Natrium could potentially play well with a renewable-heavy grid by providing steady, unchanging output like a current nuclear reactor as well as discharging stored energy in response to renewables falling off the grid.
Heatmap Illustration/Hy Stor Energy
Type: Hydrogen
Developer:Hy Stor Energy
Location: Project components located throughout Mississippi, with some in Eastern Louisiana
Size: Goal of 340,000 metric tons per year (phase one)
Operation date: 2027
Cost: Initially reported as $3 billion; recently reported as more than $10 billion. (In response to an inquiry from Heatmap, the company replied that it “will be in the multiple billions of dollars.”
Why it matters: Truly carbon-free hydrogen could unlock big emissions reductions across the economy, from fertilizer production, to steelmaking, to marine shipping. But few companies are going to the lengths that Hy Stor is gto ensure its product is really clean. The company is building the first off-grid hydrogen production facility powered entirely by wind and solar. That means Hy Stor will have no problem claiming the new hydrogen production tax credit, which requires companies to match their operations with clean energy sources by the hour — a provision that’s been contested by large portions of the hydrogen industry.
For a company that has never built anything before, the scale of Hy Stor’s Mississippi project is ambitious. The company has acquired about 70,000 acres across Mississippi and Louisiana, along with 10 underground salt domes — mounds of salt buried beneath the Earth’s surface that can be dissolved to form cavernous, skyscraper-sized storage facilities for hydrogen. Those salt domes are the key to Hy Stor’s approach, and what enables the company to rely on intermittent renewables. By storing vast amounts of hydrogen, the company will be able to deliver a steady supply to customers and will also have a backup source of energy for its own operations when wind and solar are less available.
Chief Commercial Officer Claire Behar told Heatmap the company has obtained many of the necessary permits, including for its salt caverns and the plant’s water use. It plans to begin construction at the beginning of 2025, and to have the first phase of the project “in service at scale” by 2027. Hy Stor recently announced a deal to purchase its electrolyzers, devices that split water molecules into hydrogen and oxygen, from a Norwegian company called Nel Hydrogen. It has also signed up a few customers, including a local port and a green steel company.
Heatmap Illustration/Project Cypress
Type: Carbon removal
Developers: Climeworks, Heirloom, and Battelle
Location: Calcasieu Parish, Louisiana
Size: Goal of capturing 1 million metric tons per year
Operation date: About 2030
Cost: Total project cost unknown; eligible for up to $600 million from the Department of Energy for its Regional Direct Air Capture Hubs Program.
Why it matters: Project Cypress might be the most ambitious project to remove carbon from the atmosphere under development in the world. It is a collaboration by two leading direct air capture companies, Heirloom Carbon Technologies and Climeworks, which were among the first to demonstrate their ability to capture carbon directly from the air and store it at commercial scale. Now, the two will be attempting to scale up exponentially, from capturing a few thousands tons per year to a combined million.
Last August, the Department of Energy selected Project Cypress to be one of four direct air capture hubs it will support with $3.5 billion from the Bipartisan Infrastructure Law. In March, the project was awarded its first infusion of $50 million, but the developers will have to do extensive community engagement to continue receiving funding. Battelle, the project developer, told Heatmap the project has also received an additional $51 million in private investment.
Between financing, permitting challenges, renewable energy sourcing, and community opposition, the project is sure to face a bumpy road ahead. The project and its developers have no ties to the oil and gas industry, but that hasn’t done much to win over the support of environmental justice advocates, who see the project as a dangerous distraction from cutting emissions and pollution in Louisiana. But if Project Cypress is successful, it will show the world what direct air capture looks like at climate-relevant scales.
Heatmap Illustration/NET Power
Type: Carbon capture
Developer: NET Power
Location: Ector County, Texas
Size: 300 megawatts
Operation date: Late 2027 or early 2028
Cost: About$1 billion
Why it matters: Oil and gas CEOs love to say that the problem is not fossil fuels, the problem is emissions. NET Power’s technology — a natural gas power plant with zero emissions, carbon or otherwise — could prove to be the ultimate vindication of that statement. In short, NET Power’s system recycles most of the CO2 it produces and uses it to generate more energy. It also utilizes pure oxygen, unlike typical natural gas plants that take in regular air, which is mostly nitrogen. This means that any remaining CO2 not recycled in the plant is relatively pure and easy to capture.
NET Power opened a 50 megawatt demonstration plant in La Porte, Texas, in 2018, and is developing a 300 megawatt commercial plant in Ector County, Texas, in partnership with Occidental Petroleum, Baker Hughes, and Constellation Energy. On a recent earnings call, CEO Danny Rice said the project was “expected to have a lower levelized cost per kilowatt hour than new nuclear, new geothermal, and new hydro.”
The company generated a lot of excitement among energy experts in the fall of 2021 when it announced that its La Porte project had successfully delivered power to the Texas grid. It also raised a lot of money when it went public last summer. But things have been somewhat rocky since. During a December earnings call, NET Power’s president told investors that its first commercial plant would be delayed by at least a year due to supply chain challenges. According to filings with the Securities and Exchange Commission, the company also applied for funding from the Department of Energy’s Office of Clean Energy Demonstrations last year, but was not selected. It has not yet found any third parties to license its technology or offtakers to buy energy from the Ector County plant, and noted in its recent filings that while the La Porte pilot project delivered electricity to the grid, it did not, in fact, deliver “net” power — meaning that it used more power than it generated.
A spokesperson for the company told Heatmap the La Porte facility was solely intended to “prove the technical viability of the NET Power Cycle” and not intended to produce net power. So everything’s now riding on Project Permian.
Editor’s note: This story has been updated to correct a typographical error in the amount of private investment Project Cypress has received.
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And more of the week’s top news about renewable energy conflicts.
1. Nassau County, New York – Opponents of Equinor’s offshore Empire Wind project are now suing to stop construction after the Trump administration quietly lifted its stop-work order.
2. Somerset County, Maryland – A referendum campaign in rural Maryland seeks to restrict solar development on farmland.
3. Tazewell County, Virginia – An Energix solar project is still in the works in this rural county bordering West Virginia, despite a restrictive ordinance.
4. Allan County, Indiana – This county, which includes portions of Fort Wayne, will be holding a hearing next week on changing its current solar zoning rules.
5. Madison County, Indiana – Elsewhere in Indiana, Invenergy has abandoned the Lone Oak solar project amidst fervent opposition and mounting legal hurdles.
6. Adair County, Missouri – This county may soon be home to the largest solar farm in Missouri and is in talks for another project, despite having a high opposition intensity index in the Heatmap Pro database.
7. Newtown County, Arkansas – A fifth county in Arkansas has now banned wind projects.
8. Oklahoma County, Oklahoma – A data center fight is gaining steam as activists on the ground push to block the center on grounds it would result in new renewable energy projects.
9. Bell County, Texas – Fox News is back in our newsletter, this time for platforming the campaign against solar on land suitable for agriculture.
10. Monterey County, California – The Moss Landing battery fire story continues to develop, as PG&E struggles to restart the remaining battery storage facility remaining on site.
A conversation with Biao Gong of Morningstar
This week’s conversation is with Biao Gong, an analyst with Morningstar who this week published an analysis looking at the credit risks associated with offshore wind projects. Obviously I wanted to talk to him about the situation in the U.S., whether it’s still a place investors consider open for business, and if our country’s actions impact the behavior of others.
The following conversation has been lightly edited for clarity.
What led you to write this analysis?
What prompted me was our experience in assigning [private] ratings to offshore wind projects in Europe and wanted to figure out what was different [for rating] with onshore and offshore wind. It was the result of our recent work, which is private, but we’ve seen the trend – a lot of the big players in the offshore wind space are kind of trying to partner up with private equity firms to sell their interests, their operating offshore wind assets. But to raise that they’ll need credit ratings and we’ve seen those transactions. This is a growing area in Europe, because Europe has to rely on offshore wind to achieve its climate goals and secure their energy independence.
The report goes through risks in many ways, including challenging conditions for construction. Tell me about the challenges that offshore wind faces specifically as an investment risk.
The principle behind offshore wind is so different than onshore wind. You’re converting wind energy to electricity but obviously there are a bunch of areas where we believe it is riskier. That doesn’t mean you can’t fund those projects but you need additional mitigants.
This includes construction risk. It can take three to five years to complete an offshore wind project. The marine condition, the climate condition, you can’t do that [work] throughout the year and you need specialized vehicles, helicopters, crews that are so labor intensive. That’s versus onshore, which is pre-fabricated where you have a foundation and assemble it. Once you have an idea of the geotechnical conditions, the risk is just less.
There’s also the permitting process, which can be very challenging. How do you not interrupt the marine ecosystem? That’s something the regulators pay attention to. It’s definitely more than an onshore project, which means you need other mitigants for the lender to feel comfortable.
With respect to the permitting risk, how much of that is the risk of opposition from vacation towns, environmentalists, fisheries?
To be honest, we usually come in after all the critical permitting is in place, before money is given by a lender, but I also think that on the government’s side, in Europe at least, they probably have to encourage the development. And to put out an auction for an area you can build an offshore wind project, they must’ve gone through their own assessment, right? They can’t put out something that they also think may hurt an ecosystem, but that’s my speculation.
A country that did examine the impacts and offer lots of ocean floor for offshore is the U.S. What’s your take on offshore wind development in our country?
Once again, because we’re a rating agency, we don’t have much insight into early stage projects. But with that, our view is pretty gloomy. It’s like, if you haven’t started a project in the U.S., no one is going to buy it. There’s a bunch of projects already under construction, and there was the Empire Wind stop order that was lifted. I think that’s positive, but only to a degree, right? It just means this project under construction can probably go ahead. Those things will go ahead and have really strong developers with strong balance sheets. But they’re going to face additional headwinds, too, because of tariffs – that’s a different story.
We don’t see anything else going ahead.
Does the U.S. behaving this way impact the view you have for offshore wind in other countries, or is this an isolated thing?
It’s very isolated. Europe is just going full-steam ahead because the advantage here is you can build a wind farm that provides 2 or 3 gigawatts – that’s just massive. China, too. The U.S. is very different – and not just offshore. The entire renewables sector. We could revisit the U.S. four or five years from today, but [the U.S.] is going to be pretty difficult for the renewables sector.
What I’m hearing from developers and CEOs about the renewable energy industry after the Inflation Reduction Act
As the Senate deliberates gutting the Inflation Reduction Act’s clean electricity tax credits, renewable energy developers and industry insiders are split about how bad things might get for the sector. But the consensus is that things will undoubtedly get worse.
Almost everyone I talked to insisted that solar and wind projects further along in construction would be insulated from an IRA repeal. Some even argued that spiking energy demand and other macro tailwinds might buffer the wind and solar industries from the demolition of the law.
But between the lines, and beneath the talking points and hopium, executives are fretting that lots of future investments are in jeopardy. And the most pessimistic take: almost all projects will have their balance sheets and time-tables impacted in some way that’ll at minimum increase their budget costs.
“It’s hard to imagine, if the legislation passes in its current form, that it wouldn’t impact all projects,” said Rob Collier, CEO of renewable energy transaction platform LevelTen.
Even industry analysts with the gloomiest views of the repeal say there’s plenty of projects that will keep chugging along and might even become more valuable to investors if they’re close enough to construction or operation. This aligns with recent analysis from BloombergNEF, which found the House bill would diminish our nation’s renewables build-out – but not entirely end its pace.
“The more useful way to break down which project may be hit the hardest is where the projects are going to fall in their development life-cycle,” Collier said. “Projects that have either started construction or have the ability to start construction … are going to very likely rise in terms of their appeal and attractiveness and those projects will be at a premium, if they’re able to skate through the legislative risk and qualify for tax credits.”
There is a more optimistic industry view that believes increased project costs will just be passed along to consumers via higher electricity prices. The American people will in essence have to pick up the tab where the federal tax code left it. Optimists also cite the increased use of power purchase agreements, or PPAs, between renewables developers and entities who need a lot of electricity, like big tech companies. By signing these PPAs, buyers are subsidizing the construction of projects but also insulating themselves from the risk of rising electricity prices.
The most bullish perspective I heard was from Nick Cohen, the CEO of Doral Renewables, who told me deals like these combined with rising premiums for quick energy on the grid may obviate lost credits in a “zero-incentive environment.”
“It’s not the end of the world,” Cohen told me. “If you’re in construction or you’re going to be in construction very soon, you’re fine.”
But Collier called Cohen’s prediction an “experiment” in customers’ willingness to pay for new energy: “If we’re talking about 40%, 50%, 60% of a project’s capital stack now being at risk because of tax credits, those are pretty large price increases.”
I spoke to multiple companies that have been inking massive deals as this legislation has progressed — although many were not nearly as sanguine about the industry’s future prospects as Doral. Like rPlus Energies, which disclosed last week that it closed a commitment for more than $500 million in tax equity investments for a solar and storage project in Utah. rPlus CEO Luigi Resta told me that the legislation “certainly has posed concern from our investors and from the organization” but the project was so far along that the tax equity investment market wasn’t phased by the bill.
“Many people in my company, myself included, have been doing this for more than 20 years. We’ve seen the starts and stops related to ITC and PTC in solar and wind, in multiple cycles, and this feels like another cycle,” Resta told me. “When the IRA passed, everybody was exuberant. And now the runway looks like it may have a cliff. But for us, our mantra since the beginning of the year has been ‘proceed with caution, preserve and protect.’”
However, crucially, it is important to focus on how that caution looks: Resta told me the company has completely paused new contracting while the company is completing the projects it is currently developing.
One government affairs representative for a large and prominent U.S. renewables developer, who spoke on the condition of anonymity to preserve relationships, told me that “whatever rollback occurs will just result in higher electricity prices over time.” In the near term, the only language that would truly gut projects in progress today would be “foreign entity of concern” restrictions that would broadly impact any component even remotely connected to Chinese industries. Similar language all but kneecapped the entire IRA electric vehicle consumer credit.
“It included definitions of what it means to be a foreign company that were really vague,” the government affairs representative said. “Anyone who does any business with China essentially can’t benefit from the credit. That was a really challenging outcome from the House that hopefully the Senate is going to fix.” If this definition became law, this source said, it would be the final straw that “freezes investment” in renewable energy projects.
Ultimately, after speaking to CEO after CEO this week, I’ve been left with an impression that business activity in renewables hasn’t really subsided after the House bill passed, and that it’ll be the Senate bill that undoubtedly defines the future of renewable energy for years to come.
Whether that chamber remains the “cooling saucer” it once was will be the decider.