ESS Tech, listed on the New York Stock Exchange as “GWH”, announced it has secured a $50 million investment from the Export-Import Bank of The United States (EXIM).

The funds are expected to support the expansion of ESS production capacity at its Wilsonville, Oregon plant. The company develops long-duration energy storage iron flow batteries. The investment is expected to help ESS triple its manufacturing capacity at the Wilsonville plant.

“Our technology uses earth-abundant iron, salt and water to deliver environmentally safe solutions capable of providing up to 12 hours of flexible energy capacity for commercial and utility-scale energy storage applications,” said ESS Tech.

EXIM made the investment via its Make More in America Initiative, which makes available medium- and long-term loans, loan guarantees, and insurance to finance export-oriented domestic manufacturing projects.

ESS Tech is delivering iron flow energy storage systems to customers in Europe, Australia and Africa. The company manufactures 100% of its products in the United States, with a predominantly domestic supply chain that spans 29 states.

“Our partnership with EXIM underscores the critical role that American-made clean energy technology will play in the global clean energy transition,” said ESS chief executive officer Eric Dresselhuys. “ESS’s iron flow technology is already deployed in Australia and Europe and with this agreement, we are well positioned to meet the growing needs of our current and future global customers.” 

ESS battery systems are designed to operate for 25 years, while conventional batteries last about 7 to 10 years. The battery modules, electrolyte, plumbing, and other components may well last for decades longer with proper maintenance, said the company. The battery, for example, is expected to experience zero degradation over 20,000 cycles. The long duration energy storage (LDES) system can store and dispatch electricity for 12 hours or more.

According to the Department of Energy’s ‘Pathways to Commercial Liftoff: Long Duration Energy Storage’ report, the U.S. grid needs 225 to 460 GW of LDES capacity for power market application for a net zero economy by 2060. The global LDES market is estimated to be $50 billion per year and forecast to grow significantly with a cumulative investment of up to $3 trillion by 2040, according to the LDES Council and McKinsey & Co.

The pace at which states and utilities are requiring smart inverters for new distributed solar and storage installations “generally continues to be slow,” said Steven Rymsha, Sunrun’s director of grid solutions, public policy.

That matters because work in Hawaii, he said, has shown that hosting capacity for distributed solar and storage can increase by as much as 500% on a distribution circuit where smart inverters use default settings that regulate voltage. Hawaii’s main utility has greatly expanded its hosting capacity by requiring smart inverters that meet a global standard known as IEEE 1547-2018. Rymsha made his comments in an interview.

By regulating voltage, smart inverters enable more distributed solar and storage on a distribution circuit without the need for costly utility voltage regulation hardware. That’s true not just for a primary distribution circuit, Rymsha said, but also on a customer’s secondary circuit, or service connection from the customer’s service transformer—a circuit that may serve up to 10 or more customers.

In Hawaii, California and Illinois, the earliest adopters of smart inverter capabilities, Rymsha said “the research and the real-world experience” show that the IEEE default settings for the smart inverter functions known as volt-var and volt-watt “make a lot of sense.” Even before that, in the IEEE standards development process, he said the default settings were “well vetted by utilities and other stakeholders.”

Rymsha said that while the smart inverter settings being selected by states “should go through stakeholder processes,” enabling smart inverter voltage regulation functions quickly “is going to make interconnection easier for customers today and long into the future.”

Not-smart inverters

Eight states, along with certain utilities in 13 states, now require that distributed solar and storage installations use smart inverters that meet the IEEE 1547-2018 standard, according to a tracker maintained by the nonprofit group IREC.

Yet IREC’s tracker shows that some of the states and utilities that have adopted smart inverters specify that the inverters must use a volt-var setting that does not help control voltage on a distribution circuit. Without controlling voltage, the setting, which IREC’s tracker refers to as “unity power factor,” does not improve the circuit’s hosting capacity for solar and storage.

Rymsha noted that smart inverters also have functionalities that can support the transmission grid, and that settings enabling those functionalities are now required for newly installed smart inverters in the New England grid region ISO-NE. Yet the volt-var and volt-watt settings that regulate voltage on a distribution circuit “are still not being used across that entire region,” he said.

Other states, he said, are in a similar circumstance, as they are requiring the latest inverters, but without the voltage management settings enabled. “The pace of function activation should be accelerated,” Rymsha said.

Asked whether it would be feasible for a state to call for updating the settings in smart inverters used in rooftop solar systems after the systems are installed, Rymsha said that for inverters that have an internet connection, “I am aware of new grid codes being pushed to inverters, but the process in Hawaii to do this was complicated as it required customer consent in some form.”

Consumer protection

In Puerto Rico, where the distribution utility is expected to require smart inverters starting July 1, Rymsha said Sunrun is advocating for consumer protections as it participates in stakeholder discussions about smart inverters.

Rymsha anticipates the utility will require smart inverters to use the IEEE’s default volt-var and volt-watt settings, and if so, there should be “a consumer protection package, similar to what Hawaii has rolled out,” he said. California and Maryland have also set consumer protection packages when they required that both functions be activated, he added.

Hawaii, working in collaboration with the National Renewable Energy Laboratory, used a custom setting similar to the IEEE default setting for the volt-var function, and activated volt-watt for all customers, Rymsha said, “which really revolutionized the interconnection process for everyone.” Hawaii’s main utility uses advanced metering infrastructure data to monitor voltages, he said, plus the volt-watt function which enables curtailment to maintain voltage within the proper range when needed. But “if there is excessive curtailment, the utilities are responsible to upgrade the infrastructure within a predetermined amount of time.”

“We think something like that’s needed for Puerto Rico as well,” he said.

Plug and play

Beyond seeing “a lot of opportunity” to use smart inverter settings to enable greater adoption of distributed solar and storage, Rymsha sees an opportunity to “make it like buying any other product you like,” where a customer buys the product, “and very quickly it’s being delivered to your house and operating.”

“For a lot of customers today,” he said, their expectations start out “very high, and then when they get involved in the utility processes, delays can occur without any visibility from the development community—just big, big bottlenecks.”

“As we look to electrify society, we need to look at how we can radically change utility processes on the interconnection side, to really make distributed energy resources an attractive, consumer-friendly solution. And as these get built out at scale, there’s a lot of opportunities to provide grid services; ideally, that’s all packaged up front.”

As clean energy professionals, we’re rightfully proud of the rapid progress being made in deploying solar, wind, and battery storage technologies. The plummeting costs and increasing efficiencies of renewables mean that greening the grid by 2050 is now a realistic goal. This is cause for celebration.

However, we must also reckon with an inconvenient truth: even if we achieve 100% clean electricity by mid-century, atmospheric CO2 levels are still on track to reach around 450 parts per million (ppm) by 2050 – far above the 350 ppm level considered safe for humanity. The painful reality is that the clean energy transition, while absolutely necessary, is not sufficient on its own to avert climate catastrophe.

This is the stark message of Peter Fiekowsky’s recent book Climate Restoration, which argues that we must go beyond emissions reductions to actually remove a trillion tons of legacy CO2 from the atmosphere. Only by restoring CO2 to pre-industrial levels below 300 ppm can we ensure the long-term survival and flourishing of human civilization.

Fiekowsky, an MIT-educated physicist and entrepreneur, contends that relying solely on emissions cuts to stabilize CO2 around 450 ppm is far too risky. Humans have never lived long-term with CO2 that high. The last time levels were similar was over 3 million years ago, when sea levels were 60 feet higher and global temperatures 5-8°F warmer. Allowing CO2 to remain elevated for centuries risks crossing irreversible tipping points in the climate system.

The good news is that CO2 removal at the necessary scale is technologically feasible and surprisingly affordable, costing an estimated $1-2 billion per year. Fiekowsky identifies four main approaches that could restore atmospheric CO2 to safe levels by 2050:

1. Ocean iron fertilization to stimulate plankton blooms that absorb CO2
2. Seaweed permaculture to grow and sink carbon-sequestering kelp
3. Synthetic limestone manufacture using captured CO2
4. Enhanced atmospheric methane oxidation

These nature-based and biomimicry solutions harness and accelerate the Earth’s natural carbon cycle processes. Importantly, they are permanent, scalable, and financeable – key criteria for viable CO2 removal approaches. When you consider that New York City (just one major coastal metro) is currently debating whether to spend $20 to $50 billion dollars on an ocean barrier system to prevent future storm surges from flooding the city, the $2 billion/yr price tag on climate restoration seems like a better bet.

As clean energy professionals, we must expand our focus beyond just greening the grid to include large-scale carbon removal. Here’s why:

First, it’s a moral imperative. We have an obligation to restore a safe, stable climate for future generations. Stopping emissions is necessary but not sufficient – we must clean up the trillion-ton legacy CO2 mess we’ve already created.

Second, it’s risk mitigation. Relying solely on emissions cuts without CO2 removal is an enormously risky bet on humanity’s ability to thrive in a radically altered climate state. Carbon removal gives us vital insurance.

Third, it’s economic opportunity. CO2 removal solutions like synthetic limestone can produce valuable products, creating new industries and jobs. The transition to a circular carbon economy will require major infrastructure investments.

Fourth, it’s technically synergistic. Many carbon removal approaches like ocean fertilization or seaweed cultivation could be powered by offshore wind or floating solar, creating virtuous cycles.

To be clear, carbon removal is not an excuse to slow down the clean energy transition – both are essential. But the clean energy community must broaden its vision to champion carbon removal alongside renewables deployment.

Specific actions we can take include:

• Advocate for updating climate policy goals to include restoring CO2 to pre-industrial levels (300 PPM of CO2 is worthy goal), not just emissions cuts
• Support R&D funding and commercial deployment of CO2 removal solutions
• Explore integrating carbon removal with renewable energy projects
• Educate ourselves and others on the need for atmospheric CO2 cleanup

The coming decades will be pivotal for humanity’s future. By combining a rapid shift to 100% clean energy with large-scale deployment of carbon removal solutions, we can create a true climate restoration future – one with a healthy, livable planet for generations to come. But we must act quickly and decisively. The clean energy industry has shown it can innovate and scale rapidly when needed. Now we must apply that same spirit to carbon removal. Our children’s future depends on it.

Tim Montague leads the Clean Power Consulting Group and is host of the Clean Power Hour podcast. He is a solar project developer, cleantech executive coach and consultant, mastermind group leader, entrepreneur and technology enthusiast. 

The Coalition for Community Solar Access (CCSA) released its Policy Roadmap that includes a guidebook, model legislation, inclusive solar access solutions for low-to-moderate income subscribers and consumer protection best practices. It’s intended to serve as a blueprint for states without competitive community solar programs to pass legislation that supports programs. It also provides insight into how to maximize federal funding.

“Our Roadmap boils down nearly a decade of the best lessons we’ve learned from creating community solar markets across the country into a succinct set of documents,” says Molly Knoll, Vice President of Policy, CCSA. “With many states exploring the development of new, or revamped, community solar programming and federal funds ready to deploy, this felt like the perfect time to release this helpful guide for all our advocates.”

The community solar is on the rise as it brings economic and social benefits to all Americans seeking local, clean community solar energy. By its design it lets people benefit from solar energy who may be unable to install solar either due to financial restrictions or because they do not have a suitable rooftop for solar.

Wood Mackenzie expects 7.6 GW of new community solar will come online in existing state markets between 2024 and 2028, and the national total of community solar installations is expected to pass 10 GW of cumulative capacity in 2026.

The CCSA’s aim with the Roadmap is to help the industry continue on the upward trajectory it’s currently experiencing, which requires strong programmatic and policy decisions.

The Roadmap’s release coincides with the U.S. Environmental Protection Agency is set to deploy $7 billion to state applicants through its Solar for All program, a funding opportunity that has a goal of bringing solar energy to low-income households. Recipients were chosen based on their proposals to develop programs designed to serve communities facing barriers to distributed solar deployment, with 100% of funding supporting low-income and disadvantaged communities in all 50 states the District of Columbia, Puerto Rico and territories.

Supporting low-income households

As recently shown in community solar programs and research reports from Wood Mackenzie and the Lawrence Berkeley National Lab  (LBNL) community solar has effectively expanded solar access to multifamily housing occupants, renters and low-income households. Based on a sample of 11 states, the LBNL study found that community solar adopters in 2023 were about 6.1 times more likely to live in multifamily buildings than rooftop solar adopters, 4.4 times more likely to rent, and earned 23% less annual income.

“The data speaks for itself: when states implement thoughtful policy programs that simplify income verification, billing, and expand access, we see immense growth in community solar adoption by low-to-moderate income households,” said Stephanie Burgos-Veras, senior manager of equity programs, CCSA. “We hope our Policy Solutions for Inclusive Solar Access primer can lead to more community solar programming being implemented — so that ultimately, more LMI households can benefit.”

The new CCSA Roadmap is intended to be used in conjunction with a companion document that provides Model Legislation for Community Solar Programs, that serves as a toolkit for policymakers to draft effective and sustainable community solar policies. The toolkit helps them tailor the program to community residents; kickstart the market with bill credit structure, oversight and administration; ensure long-term success by integrating community solar programs into existing utility and energy infrastructure of a state.

Also covered are potential challenges, the role of utilities, interconnection issues, program size and more. It also offers strategies to ensure that programs exist long into the future and continue to serve local residents.

Community solar legislation has been adopted in 19 states and the District of Columbia and multiple states have legislation in the works with nearly a dozen considering laws to create programs. Combined with the Solar For All program, CCSA believes that now is the time for policymakers to revisit the idea of bringing community solar to their state.

Find all the documents in the Policy Roadmap here under the “CCSA & Other Resources” tab.

From pv magazine Global

Summer weather and a heat dome have brought increased irradiance to both US coasts, with the strongest impact in the North East, while New Mexico and regions through the midwest experienced below-average irradiance due to increased cloud cover and atmospheric disturbances, according to analysis using the Solcast API.

Much of the continental United States saw irradiance moderately above average, 5-10% above historical June averages, with the increase most notable along the East Coast. The “heat dome” that dominated much of June was accompanied by upper-atmosphere subsidence which suppressed cloud formation, allowing more sunlight to reach the ground. In contrast, the Gulf of Mexico experienced increased precipitation and cloudiness. However, prevailing winds kept most of these clouds offshore, except for the tip of Florida. The area around the Great Lakes saw up to 10% below average irradiance due to the additional heat enhancing evaporation and cloud formation.

Despite the heatwave, New Mexico saw irradiance 5-10% below typical levels. This deviation was caused by a tropical disturbance in the Gulf of Mexico, which was observed on June 19. This disturbance brought moisture and atmospheric instability, triggering thunderstorms over New Mexico a few days later.

These thunderstorms caused flash floods and large hail in the region. While these events are not widespread enough to fully extinguish the wildfires across the state, it has impacted solar panel performance. Hail can damage and destroy solar panels, but many utility-scale solar farms in this latitude employ single-axis tracking systems that can stow panels in a vertical position to reduce damage risk. Smoke from wildfires also impacts irradiance by soiling panels and reducing light transmission through the atmosphere.

This year, the Summer Solstice happened on June 20. As the sun reaches its highest point in the sky in the Northern Hemisphere, irradiance also typically peaks around this time of year across North America. However, in Central America, this is somewhat offset by the
increased cloudiness of the tropical wet season.

Solcast produces these figures by tracking clouds and aerosols at 1-2km resolution globally, using satellite data and proprietary AI/ML algorithms. This data is used to drive irradiance models, enabling Solcast to calculate irradiance at high resolution, with typical bias of less than 2%, and also cloud-tracking forecasts. This data is used by more than 300 companies managing over 150GW of solar assets globally.

From pv magazine Global

The Chinese Module Marker (CMM), the OPIS benchmark assessment for TOPCon modules from China was assessed at $0.100/W, down $0.005/W week-to-week. Mono PERC module prices were assessed at $0.090/W, down $0.005/W from the previous week. The new record lows for both prices according to OPIS data comes as market activity remains subdued on low demand.

Module makers have reduced prices in a bid to secure new orders and maintain cash flow with tradable indications for TOPCon modules heard at $0.10/W Free-on-Board (FOB) China.

Solar modules exported to Europe continue to contend with elevated freight rates on matters in the Red Sea. OPIS heard freight rates of about $0.0164-0.0175/W (about high $6,000s-$7,000/FEU) for shipments from Shanghai to Rotterdam. While this has affected shipments, it presents an opportunity for module sellers to reduce their inventories in Europe.

A market observer said that prices during Intersolar did not move and remained around $0.10/W FOB China (+/-0.3cts) and that despite the high installations season just starting, the installation demand for Europe this year did not seem very strong, at least in the utility-scale space.

Latin America continues to look weak with the price competition in this market described as “intense” by a module seller. Prices in the Brazilian market are generally lower than in other markets as buyers are price-sensitive. TOPCon prices to Brazil had fallen to the range of $0.08-0.09/W FOB China with prices at the low end offered by Tier2-3 module sellers, the module seller added.

A buyer noted that current U.S. Delivered Duty Paid (DDP) TOPCon prices have risen to the low-to-mid $0.30/W range. This pricing includes the 201 bifacial tariffs but excludes the new antidumping/countervailing duties. With the exemption set to lapse mid-week, another market source told OPIS that “any new deals would be subject to the 14.25% Section 201 tariffs and will likely push pricing into the mid $0.30s/W in 2024”.

Domestic Chinese demand remained weak amid mounting inventory pressure. Further price cuts in the coming weeks were expected as module sellers clear inventories to generate cash flow. The majority of market participants OPIS surveyed expected TOPCon prices to drop below CNY0.8/W or $0.099/W on a FOB China equivalent, which is the current cost of production for integrated producers.

The operating rates of integrated module sellers remained between 60-80%, according to the Silicon Industry of China Nonferrous Metals Industry Association. Estimates of June module production capacity stood at 50 GW, down from 52 GW previously expected and down 5 GW from May, the association said.

China exported 83.3 GW of modules in the period January-April marking a year-on-year increase of 20%, according to latest data from China’s Ministry of Industry and Information Technology. The total value of the module shipments for the period January-April reached $12.7 billion.

Looking ahead in the FOB China market, broader bearish conditions prevent any upticks in module prices in the short term although continued production cuts into July could give some respite to supply pressures.

OPIS, a Dow Jones company, provides energy prices, news, data, and analysis on gasoline, diesel, jet fuel, LPG/NGL, coal, metals, and chemicals, as well as renewable fuels and environmental commodities. It acquired pricing data assets from Singapore Solar Exchange in 2022 and now publishes the OPIS APAC Solar Weekly Report.

From pv magazine Global

The latest supply chain report from Sinovoltaics, the Hong Kong-based technical compliance and quality assurance company, covers the North American manufacturing hub, tracking factory size, location, owner, current and planned capacity. It provides details on 95 factories producing PV modules, cells, wafers, ingots, polysilicon, and metallurgical-grade siliconin the region, up from 81 in the first quarter.

The Sinovoltaics Supply Chain Map (SSCM) – North America for Q2 2024 notes 42 GW of total module production capacity spread across Mexico, Canada, and the United States, which manufacturers plan to double to 84 GW in the coming 3 to 6 years. A Sinovoltaics spokesperson told pv magazine that the figures represent “nameplate capacity.”

The report presents data from publicly available sources, as well as Sinovoltaics contacts with manufacturers. “The report gives insights into the theoretical capacity if the factories are running at 100%,” a spokesperson from the company said. “Our data are based on the press releases that we’ve received from different manufacturers and different research, and marketing analysis documents that we’ve seen.”

There are ten more manufacturers included in the second quarter report than the previous one, a mixture of thin film, TOPCon, and perovskite tandem technology companies. The additions are Ascent Solar, Astronergy, Boway Alloy, Caelux, Great Lakes Solex, NanoPV, Prism Solar, Runergy, Solaria, and Ubiquity Solar.

The analysts noted constraints in the region’s supply chain at the cell and wafer nodes. Cell production is at 8 GW and growing to 55 GW in the coming 3 to 6 years, while wafer production is to grow from 3.2 GW to 24.5 G.

The Sinovoltaics team noted the CubicPV decision to halt silicon wafer production to focus on tandem perovskite technology and REC Silicon’s plant closure in Butte, Montana, observing that the market had not moved yet to fill the void.

Sinovoltaics has been tracking the development of PV manufacturing hubs and began publishing a series of free quarterly reports this year, mapping production in India, North America, Southeast Asia, and Europe

Wendy’s enrolls in community solar to power 130 locations Through a partnership with Ampion, Wendy’s restaurants will access renewable energy certificates to offset carbon emissions.

Recurrent Energy transfers $103 million in tax credits for Oklahoma project The owner and operator of the 160 MW North Fork Solar project signed the tax credit facilitation agreement with Bank of America.

IEA-PVPS releases fact sheet on environmental life cycle assessment of PV Systems The updated IEA PVPS Task 12 Fact Sheet provides a comprehensive assessment of the environmental impacts associated with PV systems. It highlights the significant advancements made in PV technology, emphasizing improved efficiencies and reduced environmental footprints.

Generac acquires commercial and industrial energy storage provider The company acquired engineering, procurement, and construction firm PowerPlay Battery Energy Storage Systems.

Generac Power Systems, a provider of home backup generators, battery energy storage, and other power products, announced it has acquired PowerPlay Battery Energy Storage Systems, an engineering, procurement, and construction (EPC) firm.

PowerPlay specializes in turnkey battery energy storage systems for commercial and industrial customers, with systems sized up to 7 MWh. It is a division of Sungrid, an energy storage EPC and operations and maintenance company.

Generac said the acquisition will help the company offer a more complete ecosystem of products and solutions to C&I customers.

The PowerPlay business will continue its operations in Cambridge, Canada, and serve as a dedicated research and development facility for Generac’s C&I battery energy storage system solutions. SunGrid Solutions will continue its energy storage EPC operations across the United States and Canada, specializing in solutions ranging from 10 MWh to 1 GWh.

“Various factors contribute to the need for energy storage, including the uptake of distributed solar, increased electrification of C&I facilities, rising utility rates, and possibility that the central grid can experience fluctuations due to weather, blackouts, or lack of infrastructure,” said Generac. “[Battery energy storage] systems up to 7 MWh are commonly deployed in C&I enterprises, including retail stores, restaurants, office buildings, manufacturing facilities, and healthcare facilities.”

Energy storage deployment continues to rise nationwide. Across all segments, Wood Mackenzie expects 12.9 GW / 35.8 GWh of storage to be installed in 2024. In its quarterly report, the firm raised its five-year forecast for grid-scale installations by 5% and residential sector installations by 8%. The five-year commercial, community, and industrial forecast was cut by 34% after the California Public Utilities Commission (CPUC) made an unfavorable ruling on community solar. However, Wood Mackenzie sees a strong value proposition for C&I storage for years to come.

“The CCI segment continues to see the highest barriers to growth in the near-term, but its strong value proposition and emerging value streams will make it an exciting growth segment in the later years of our ten-year forecast,” said Wood Mackenzie.

From pv magazine Global

IEA PVPS Task 12 (PV Sustainability Activities) has released an updated Fact Sheet, shedding light on the environmental impacts of photovoltaic (PV) electricity. This Fact Sheet, titled “Environmental Life Cycle Assessment of Electricity from PV Systems“, offers crucial insights into PV sustainability and highlights key advancements as well as current data in PV technology.

Life Cycle Assessment: A Comprehensive Overview

Life Cycle Assessment (LCA) is a detailed method used to quantify and assess the material and energy flows, as well as emissions, throughout the life cycle stages of PV systems. These stages include manufacturing, transport, installation, use, and end-of-life. The manufacturing phase encompasses resource extraction, raw material production, and the creation of wafers, cells, panels, inverters, and mounting structures. Transport covers the distribution logistics, while installation involves setting up roof-mounted systems and cabling. The use phase evaluates the system’s performance over a typical 30-year operational period, including maintenance. Finally, the end-of-life stage addresses dismantling, recycling, and waste management processes.

The updated Fact Sheet primarily focuses on a typical residential PV system in Europe. This system is defined by a roof-mounted PV setup, an annual production rate of 976 kWh/kW, and an in-plane irradiation of 1,331 kWh/m². It includes PV panels, cabling, mounting structure, inverter, and installation, with a linear degradation rate of 0.7% per year and a service life of 30 years for panels and 15 years for inverters.

Evaluating PV Module Technologies

IEA PVPS Task 12 assesses four PV module technologies, each with distinct efficiencies: Cadmium-Telluride (CdTe) at 18.4%, Copper-Indium-Gallium-Selenide (CIS/CIGS) at 17.0%, Multi-crystalline Silicon (multi-Si, BSF) at 18.0%, and Mono-crystalline Silicon (mono-Si, PERC/TOPCon) at 20.9%. These efficiencies are critical in determining the environmental impacts and performance of each technology.

Key Findings from the Fact Sheet

Non-renewable energy payback time (NREPBT) is the period required for a renewable energy system to generate an amount of energy equivalent to the non-renewable energy used in its production. The study reveals an NREPBT of approximately one year for the evaluated PV systems, indicating a swift return on energy investment.

PV systems dramatically reduce greenhouse gas emissions compared to fossil fuel generators. The carbon footprint for producing 1 kWh of solar electricity ranges from 25.2 to 43.6 g CO2 equivalent, far lower than the up to 1 kg CO2 per kWh emitted by fossil fuels. The study also examines additional environmental impacts, including resource use of fossil fuels (0.35 to 0.52 MJ per kWh), resource use of minerals and metals (4.6 to 5.3 mg Sb equivalent per kWh), particulate matter (1.0 to 4.0 incidences per kWh), and acidification (0.18 to 0.36 mmol H+ equivalent per kWh).

When comparing current data with previous years, the study highlights significant reductions in greenhouse gas emissions by up to 17% in some technologies, thanks to improvements in manufacturing and an increase in module efficiency.

Conclusion

The detailed life cycle assessment methodology employed in this study provides valuable insights into the entire life cycle of PV systems, from manufacturing to end-of-life management. This holistic approach ensures that all environmental impacts are considered, enabling more informed decision-making for both policymakers and industry stakeholders.

Please download the Fact Sheet here.

IEA PVPS Task 12 aims to quantify the environmental profile of PV systems relative to other energy technologies and address critical environmental, health, safety, and sustainability issues to support market growth.

For further information please contact the IEA PVPS Task 12 Managers: Garvin Heath and Etienne Drahi.

Recurrent Energy, a subsidiary of Canadian Solar, signed a $103 million tax credit facilitation agreement with Bank of America for its North Fork Solar Project.

The tax equity agreement is Recurrent Energy’s first production tax credit (PTC) transaction and first tax credit transfer transaction. Recurrent reports that by transferring tax credits to Bank of America, it can access funding more quickly and efficiently.

In April the Internal Revenue Service (IRS) released final guidance for the transfer of clean energy tax credits, a provision within the Inflation Reduction Act and the Creating Helpful Incentives to Produce Semiconductors (CHIPS) act that allow tax credit owners to sell their credits to other entities with a tax appetite.

Under a tax credit transfer transaction, renewable energy developers and owners can sell tax credits for cash, making financing easier for new clean energy projects. The transferability option is generally open to the entities that are not covered by the direct pay option. More information in the frequently asked questions section can be found here.

Oklahoma Municipal Power Authority (OMPA), which serves 42 municipally owned electric systems in Oklahoma, will purchase 100% of the energy produced by North Fork Solar under a 15-year agreement. This marks the first solar project in OMPA’s energy mix. Recurrent Energy will continue to own and operate the project long-term.

“This addition will further diversify our energy sources and provide our member cities with more energy options to offer their customers,” said David Osburn, OMPA general manager. “We look forward to maintaining a long-term relationship with Recurrent Energy.”

The 120 MWac North Fork Solar project, which sits on 1,012 acres in Kiowa County, Oklahoma, will provide enough electricity to power the equivalent of 35,000 homes year.

This project greatly increases the amount of solar installed in the state of Oklahoma, which ranked 46^th for installed capacity in Q1 2024 with 189 MW, according to the Solar Energy Industries Association. At that time the Covington Solar Farm at 13.2 MW, which came online in 2017, was a landmark project.

Construction by Blattner began in August 2023 and was compete in June  2024 with approximately 250 people employed during peak construction and three permanent jobs during operation.

According to Recurrent Energy’s website, the project used construction methods to minimize grading and removal of soil, and preserved topsoil was redistributed across the graded areas to assist in growing ground cover as quickly as possible.

Recurrent Energy reports that during the project’s development and construction, the company supported local initiatives, including the Snyder 4-H and FFA, Snyder Prom, and Cyclone Educational Foundation. Now that it’s operational, the solar project will contribute about $26 million to community services.

Recurrent Energy began developing North Fork Solar in 2018. NordLB and Rabobank provided project financing for North Fork Solar. CRC-IB and Latham & Watkins advised Recurrent Energy on the tax credit transfer transaction.

Community solar provider Ampion Renewable Energy is partnering with The Wendy’s Company to help the restaurant chain source renewable energy. By signing onto community solar projects, companies like Wendy’s support the generation of renewable electricity for local grids.

Nearly 100 company-operated Wendy’s restaurants and nearly 40 franchise restaurants in New York, Illinois, and Massachusetts are now enrolled in Ampion+, a product that enables organizations t secure renewable energy certificates (RECs). RECs are a green power procurement strategy that electricity consumers, such as Wendy’s, use to substantiate renewable electricity use claims.

The result of the agreement, according to Ampion, is that the enrolled restaurants will source between 30% and 100% of their energy from solar without the need to install solar panels onsite. Wendy’s plans to increase the number of restaurants enrolled in Ampion’s community solar program as additional solar generation capacity comes online and more franchise restaurants enroll in the program.

“We are excited about the opportunity this partnership provides our Company and franchise restaurant operators by making it easier and more accessible to source clean energy while ultimately realizing cost savings,” said Steven Derwoed, vice president, global design & construction at Wendy’s. “We are advancing progress toward our emissions reduction goals through community solar participation and RECs. It’s a win-win for the Company and our franchisees.”

Last year, Wendy’s set near-term science-based targets to reduce absolute Scope 1 and 2 emissions by 47%, and Scope 3 emissions from franchisees by 47% per restaurant by 2030, from a 2019 baseline.

Through Ampion, Wendy’s locations have enrolled approximately 27.5 million kWh in community solar or the equivalent electricity needed for 2,200 homes for one year. Each kilowatt hour will be accounted for, tracked, and assigned ownership to a specific restaurant location via RECs through the Ampion+ product.

“As the need for reducing carbon emissions grows, community solar combined with RECs provides a solution for environmental sustainability in the corporate sector that is both achievable and affordable, while enabling companies to quantify and disclose their progress in a standardized manner,” said Nate Owen, CEO and founder of Ampion. “We’re seeing more large companies actively seeking sustainable solutions through community solar. This partnership with Wendy’s demonstrates that Ampion is able to support these organizations in reducing emissions and putting more renewable energy on the grid for local communities.”

Community solar is expanding rapidly in the U.S. with 22 states, including Washington D.C. that have policies supporting third-party shared or community solar. According to the Coalition for Community Solar Access, 6.6 GW of community solar generation capacity has been installed to date, and Wood Mackenzie’s most recent U.S. community solar market outlook predicts that there will be 14 GW power installed across the country by the end of 2028.

Earlier this year, Ampion surpassed 1 GW of community solar generation under management. Currently active in nine states and counting, Ampion acquires and manages subscribers of all types, from housing authorities, municipalities, and enterprises such as Wendy’s, to small businesses and residential subscribers. Ampion reports that it acquired thousands of low-to-moderate income subscribers in 2023, expanding access to those who need savings the most.

Solar ingot and wafer manufacturing coming to Oklahoma The Norwegian company, Norsun, announced an investment of $620 million in a 5 GW ingot and wafer facility planned in Tulsa.

People on the move: Spruce Power, ConnectDER, Amp Energy and more Job moves in solar, storage, cleantech, utilities and energy transition finance.

pv magazine interview: ‘Oversupply issues may continue in 2025’ As part of our Intersolar 2024 interview series, pv magazine spoke with Amy Fang, Senior PV analyst at InfoLink Consulting, about new solar factories coming online and decreasing solar modules prices. She says the downward trend may continue until the first half of next year, with prices reaching $0.07/W, and estimates global module demand for this year could reached between 470 GW and 500 GW.

Back contact solar beats mono PERC at lifetime energy generation A new analysis finds that back contact solar shows an average lifetime energy generation increase of 16.0% over mono PERC. The paper also says back contact had an average 9.7% shorter payback time and 10.7% lower LCOE across all modelled locations.

New York governor urged to double solar deployment goal Currently New York has a state target of 10 GW deployed by 2030. The state’s Solar Energy Industries Association has called for a new target of 20 GW of distributed solar by 2035.

World4Solar held a launch event at its warehouse in Miami, Florida to introduce HelioWing, a pre-constructed solar canopy structure.

The HelioWing is available in two base models, HelioWing 5 with 7.38 kWp and the HelioWing 7 with 9.84 kWp. The HelioWing 7 roof is made of 24 Aptos 400 W bifacial solar panels. The company uses Sol-Ark 12kW hybrid 2-phase inverters for its canopy.

The canopy design can be customized with features like storage capacity or a carport with a built-in EV charger. The modular energy systems come preassembled and preconfigured. The unit comes equipped with motion sensor LED light strips.

HelioWing 7 measures 22.7 feet by 22.4 feet by 13.10 feet and has a 500 square foot gap-free solar roof.

World4Solar noted that the canopy should take about six hours to install, when set up by a certified installer on a prepared foundation. The HelioWing can be used grid-tied or off-grid. To operate off-grid, or to store electricity for later use, battery packs are available ranging from 8.3 to 24.9 kWh.

Two available Level 2 chargers per unit work with all electric vehicles and add 25 miles average of range per hour of charging.

HelioWing is waterproof rated and has an average 20-year life span. The system comes with a 10-year warranty. The main structure is listed at MSRP $37,180, while the modules are priced at $5,044 and the inverters $6,825. A Tesla level 2 EV charger is priced at $1,625 while the battery system can range from about $7,500 to over $18,000 depending on products selected. The company also offers what it calls a “hurricane-hardened” canopy.

The New York Solar Energy Industries Association (NYSEIA) has issued a report to Governor Kathy Hochul, requesting a raised target for the state’s distributed solar targets.

NYSEIA specifically requested an increased target for the buildout of distributed solar projects, which are typically installed on rooftops, carports or other built-environment locations for homes and businesses.

Under New York’s current climate strategy, the state targets 10 GW of distributed solar by 2030. NYSEIA has called for this to be doubled five years later, reaching 20 GW by 2035.

NYSEIA projects achieving this goal would lead to $50 billion in gross electric bill savings; $3 to $4 billion in revenue for rural landowners, municipalities and school districts; and support an additional 15,000 jobs in the solar industry.

New York is a leader in distributed solar buildout. About 90% of the state’s solar capacity is distributed, a much higher percentage than solar heavy states like California and Texas that have invested heavily in large, centralized utility-scale projects.

New York added more than 800 MW of distributed solar capacity last year alone and is on track to surpass 6 GW by the end of 2024, one year ahead of schedule.

“Scaling up distributed solar deployment will deliver cost-effective progress toward New York’s overall climate goals while delivering immense benefits to New York’s environment, economy, and working families,” said Noah Ginsburg, executive director, NYSEIA.

In 2019, New York enacted the Climate Leadership and Community Protection Act (CLCPA), directing New York to be powered with 70% renewable energy by 2030, 100% renewable energy by 2040, and a carbon neutral economy by 2050. 

Since then, a wave of high-profile utility-scale renewable project cancellations has jeopardized the feasibility of achieving 70% renewable energy by 2030, said NYSEIA.

“As New York struggles to meet its ambitious renewable energy mandates, legislative leaders and regulators must take decisive action,” said Ginsburg.

In 2023, Governor Hochul enacted a 10-point action plan to get utility-scale renewable projects back on track. However, NYSEIA said while utility-scale projects are important, they are not enough to meet New York’s mandates. To double solar cumulative solar deployment in six short years, distributed rooftop solar can be deployed rapidly to fill the gap.

There is hope yet for New York to achieve its climate goals. Solar deployment has grown at an average 31% annual growth from 2013-2022. To reach the new 20 GW by 2035 goal, the state will need to sustain 7-10% annual growth in deployment. NYSEIA said this was driven in part by the state’s leading community solar program.

NYSEIA advocates for the following policy changes to achieve the goal:

• Interconnection reform and flexible interconnection to lower clean energy costs and accelerate deployment 
• Streamlined permitting for rooftop and community solar
• Virtual power plant programs and dynamic rate design to compensate distributed solar and energy storage for exporting power when and where it’s needed
• Continued investment in New York’s nation-leading community solar programs to provide even more direct bill savings to low-income New Yorkers

“Distributed solar has performed so well in New York because it fits the nature of our state,” said Senator Pete Harckham, chair of the environmental conservation committee. “We have a unique mix of urban, suburban, and rural communities that can support a diverse portfolio of renewable energy projects, and it’s time we lean into our character as a state.”

Find the full roadmap here.

• David Rogers, founder & CEO of Amp Energy, welcomes Andy Hoffman, CFA, to the team as its newest Chief Financial Officer, joining from The Carlyle Group, where he led the origination, structuring, and underwriting of private credit real asset transactions within the firm’s $5B+ AUM Infrastructure Credit platform.
• Matthew Dorsen just joined Deriva Energy as their new Director of Development.
• Jiwan Singh is announcing their new role as Director of Engineering at Atwell, LLC.

North America’s leading renewable energy search firm

Norsun plans to invest $620 million in a new 5 GW silicon ingot and solar wafer manufacturing facility on a 60-acre greenfield site in Tulsa, Oklahoma.

The Inflation Reduction Act (IRA) has motivated solar module manufacturers to build manufacturing facilities in the U.S; however, very few factories are planned for the production of ingots, wafers and cells. This shortage leaves U.S. solar module makers reliant on imports, mainly from China.

Production at the new Norsun plant is expected to begin in 2026, bringing much-needed U.S.-made silicon ingots and wafers to the supply chain, as well as 320 jobs to the Tulsa area. Norsun reports that production can be expanded up to 10 GW.

“Our business plan has an ambitious timeline, so we knew we needed a partner who can work fast and efficiently to meet the critical need for American-made energy,” said NorSun CEO Erik Løkke-Øwre. “Oklahoma impressed us even before our selection journey – its robust clean energy, manufacturing ecosystem and workforce development programs were already on our radar, and its competitive business offerings and site acceleration options solidified our decision.”

Norsun, founded in Norway in 2007, specializes in the production of monocrystalline ingots and wafers for ultra-high efficiency solar cells. The expansion was facilitated by the Oklahoma Department of Commerce and Tulsa Airports Improvement Trust.

“I’m proud to welcome Norsun to Oklahoma, and I’m thrilled that Oklahomans will benefit from hundreds of new jobs in the Tulsa area and a $620 million capital investment,” said Governor Kevin Stitt. “Our pro-growth policies, workforce development efforts, and ‘more of everything’ energy approach make us an incredible state to invest in, and I’m glad NorSun can be a part of it.”

From pv magazine Global

A new white paper from research and consulting firm Exawatt examines and contrasts key module parameters across various technologies to assess the potential value these technologies may offer for residential and commercial applications. The white paper, authored by Molly Morgan and Alex Barrows of Exawatt, draws on analyses from the company’s Solar Technology and Cost Service.

The paper reveals that, in the modelling performed, back contact (xBC), heterojunction (HJT), and tunnel oxide passivated contact (TOPCon) technologies may exhibit meaningful improvements in lifetime energy generation compared to mono passivated emitter rear contact (PERC) technologies. Through detailed modelling exercises, the document evaluates how xBC, HJT, and TOPCon contribute to increased clean energy generation and potential financial savings depending on specific system parameters.

In both residential and commercial system modelling scenarios, the authors found that xBC stands out as the top performer, showing an average increase of 16.0% over mono PERC, while HJT and TOPCon offer generation gains of 11.4% and 8.2%, respectively.

Furthermore, the white paper delves into the profitability of residential and commercial installations through assessments of payback time and levelized cost of electricity (LCOE). Despite their premium pricing, xBC, HJT, and TOPCon technologies demonstrate enhanced profitability in both modelling scenarios in comparison to the previously mainstream mono PERC. Among these technologies, xBC emerges as the frontrunner, boasting an average 9.7% shorter payback time and 10.7% lower LCOE across all modelled locations.

While small cost reductions may still be achieved in the current PV industry, the white paper outlines that these are relatively minor in comparison to the potential efficiency gains offered by advanced technologies. High module efficiency is key to driving down system cost-per-watt, payback time, and LCOE, since it can drive down the per-watt costs of many key non-module costs such as labor and mounting.

The white paper underscores the importance for distributors, installers, and system owners to grasp the value proposition of high-performance technologies for informed decision-making on which technology has the greatest value for a specific application.

The authors conclude that as the industry continues to prioritize performance improvements over cost reductions, embracing high-performance PV technologies can pave the way for enhanced efficiency, cost savings, and sustainable energy solutions.

GCL Perovskite, a branch of GCL Tech within the GCL Poly and GCL Solar group, introduced their latest perovskite and perovskite-silicon tandem solar modules. A key highlight was the public IEC test documentation, indicating they may have conquered the perovskite degradation challenge. The company plans to incorporate this technology in the top layer of their tandem modules, aiming for efficiencies above 27% in limited deployment testing next year.

The Solar Roll by Apollo, featured in the main image above, is a flexible roll measuring 20.1 feet in length and 6.6 feet in width. This innovative setup combines six 300-watt solar panels into a 1.8 kW array capable of generating more than 10 kWh in a single day. The unit, equipped with MC4 connectors, is designed for easy integration with any standard solar inverter.

Throughout the three days of Intersolar, as detailed on the pv magazine Intersolar Live Blog pages – Day 1, Day 2, and Day 3 – attendees witness an impressive array of battery products. Numerous manufacturers showcased their latest offerings, particularly focusing on home battery solutions.

EcoFlow’s latest release, the PowerOcean Plus, represents a significant increase in residential system size and capacity. This smart hybrid inverter can manage up to 40 kW solar input with a 29.9kW AC output. Notably, it can support up to 60 kWh of battery capacity, 15 kWh more than its predecessor. Kevin Benedict, EcoFlow’s product and solutions manager, explained that this upgrade was a direct response to customer demand for larger systems to optimize home solar use and EV charging.

The presence of electric vehicles and their charging infrastructure was also a focal point at the event.

The Evum-motor aCar, showcased with a solar panel cleaning robot strapped to its flatbed, is tailored for operations and maintenance tasks. Starting at €33,990, this versatile vehicle is offered in several configurations: the base model features a 16.5 kWh battery with a range of 91 km. Additional options include a 23 kWh battery, which extends the range to approximately 128 km for an additional €4,290, and a 33 kWh battery that offers up to 203 km for an additional €10,890. Available in six base packages, the aCar punches above its weight with a payload capacity of 1,100 kg and a towing capacity up to 1,500 kg.

The aCar’s design, including its 1.5 meter width, allows it to fit comfortably between the rows of panels on solar farms, enhancing its utility. Its low-speed torque is specifically advantageous for traversing loose and steep terrain, facilitating the transport of essential hardware and personnel to less accessible areas. The inclusion of the solar panel cleaning robot underscores the vehicle’s practical application in maintaining and operating remote or large-scale solar operations.

Electric bike charger econec shared three electric bike chargers: the eBike Box micro for home use, eBike Box mini C for businesses, (featured in the image below), and eBike Box Vision for public charging. A notable feature of these systems is their customizable charger. Representatives noted that the e-bike industry has around 25 charging standards, with the public charging model, the eBike Box Vision, accommodating up to five unique plugs. Although Bosch dominates the market with 50% to 60% of all charger adapters, it offers two different types of connectors. Currently focused primarily on the European market, Econec is actively seeking U.S. partners as it works to expand its certifications.

Aiko is poised to launch the ABC Infinite Gen 3 solar module range, with efficiencies ranging from 24.2% to 25.2% in the fourth quarter. The standout 650 watt module, featuring 25.2% efficiency, aims to be the highest efficiency module globally upon its release. These products will be produced in the company’s two manufacturing facilities, with capacities of 10 GW and 14 GW of modules per year. A significant efficiency enhancement in these modules is the relocation of the busbars to the backside of the solar panels. While this adjustment reduces the bifaciality value to nearly 70%, it opens more silicon to face the sun on the front site, white significantly improving shade management capabilities.

Georg Giglinger, an environmental engineer, shared via Twitter what may have been the highest wattage module at Intersolar: Tongwei’s 765.18 watt rated, 24.63% efficiency panel.

Announced directly from the floor in Munich, Germany, Nextracker has acquired specialty ground screw manufacturer Ojjo in an all-cash transaction valued at approximately $119 million. Ojjo’s truss systems are designed to use half the steel of conventional foundations, aim to reduce grading requirements, and would be the foundation that supports NexTracker’s motors and torque tubes.

The pv magazine team at Intersolar Munich 2024 included over 30 representatives from regions such as Ireland, England, Western and Southern Germany, the U.S., among others.

Meyer Burger set to begin production at U.S. module factory The relocation of the photovoltaic manufacturer’s core business from Germany to the USA is taking shape. Production of heterojunction solar modules is starting and financing for a new cell plant is progressing.

Solar tax transfer for smaller projects: Dissecting a $600,000 tax credit transaction Basis Climate has closed its smallest IRA transferable tax credit deal to date,  marking the end of an era dominated by million-dollar minimum tax credit transactions.

Origami Solar sets up regional fabrication of steel solar panel frames Partnerships with steel equipment producers in Ohio and two locations in Texas will enable Origami to have its steel solar module frames shipped from fabricator to module manufacturer in one to two days, the company says.

‘Module prices surprisingly keep going down’ As part of our Intersolar 2024 interview series, pv magazine spoke with Yana Hryshko, head of Solar Supply Chain Research for Wood Mackenzie, about overcapacity, declining panel prices and expected PV demand for the next years. She revealed that Chinese module procurement schemes are currently seeing unprecedented, “ridiculously” low bids, but she also noted that the $0.08/W threshold may now be difficult to exceed. Hryshko also expects many manufacturers to backpedal on previously announced capacity expansion plans and renegotiate module supply contracts.

Cultural considerations for international solar expansion Each region has a different way of doing things, whether it’s selecting sites, managing employees, or implementing manufacturing standards. Companies looking to expand into foreign markets need to be prepared to deal with these cultural differences, says Clean Energy Associates (CEA) Vice President Mark Hagedorn.

City of Detroit to install solar in mostly vacant neighborhoods Three Detroit neighborhoods were chosen as sites for solar facilities. The City plans to build 33 MW of solar to power its municipal buildings.

‘We expect solar panel prices to stabilize in the second half of the year’ At Intersolar Europe 2024, pv magazine spoke with Edurne Zoco, executive director, Clean Energy Technology at S&P Global Commodity Insights, about module price trends, increasing solar demand and PV manufacturing outside China. She claims panel prices may stabilize in the second half of this year or in early 2025 and says top seven Chinese manufacturers may even continue with capacity expansion plans. She also believes that, without further substantial incentives, Europe will not be able to recreate a domestic PV supply chain.

Origami Solar announced partnerships with three steel fabricators who will domestically produce steel solar module frames. The fabricators include with Welser Profile of Valley City, Ohio; Priefert, of Mt. Pleasant, Texas; and Unimacts of Houston, Texas. Origami expects to be able to ship steel frames to customers in the first quarter of 2025, and by producing regionally says that frames will get from the fabricator to the module manufacturer in one to two days.

“America has one of the world’s strongest steel industries” said Origami Solar CEO Gregg Patterson. “We have the energy efficient steel mills and the world-class fabricators that can produce every solar frame America will ever need.”

Origami Solar, founded in 2019 and based in Bend, Oregon, is a pv magazine 2023 award winner for manufacturing. The company produces patented, steel solar module frames that are said to lower cost and improve module performance. The company reports that the frames are made of “green” recycled steel, thereby reducing greenhouse gases by up to 93%, representing a reduction of 80 kg per module or 200 metric tons per MW.

A recent report by Wood Mackenzie and Origami Solar notes that while the U.S. is working toward building up its domestic module manufacturing, thanks for the IRA, a less well-known problem is U.S. dependence on aluminum module frames. The majority of these are currently imported from East and Southeast Asia, and the report says that they are all made from carbon-intensive aluminum.

Origami sees an opportunity to supply module manufacturers in the U.S. market who are switching from imported aluminum frames to domestically made steel frames. Its use of recycled steel from suppliers in the U.S. and Europe in its frames give it a competitive edge when it comes to greenhouse gas scoring as assessed by Boundless Impact

Patterson points out that by having regional fabrication centers in the U.S., customers will avoid “shipping issues, labor strife, or impoundments delaying the arrival of the frames they need.” He added that by procuring domestically produced steel frames customers won’t have the worry of “geopolitical tensions” or “ever-increasing tariffs.” In light of recent news about fragile solar panels, he noted that steel frames may alleviate the risk of frames failing to support ever-larger solar panels.

Switching to domestically produced products across the solar supply chain has the further benefit of supporting good-paying jobs.

“Thanks to our partnership with Origami, we were able to expand our investments in the solar industry, keep our Benton, Arkansas facility open, keep our current employees hard at work and expand to up to 70 additional skilled workers over the next three years,” said Rocky Christenberry, Priefert’s executive vice president

From pv magazine Global

The City of Detroit announced it has selected three sites for its Solar Neighborhoods initiative, which seeks to develop solar facilities on mostly vacant neighborhoods throughout the city. 

Detroit city-owned buildings use a collective 33 MW of electricity. The city seeks to meet all this demand with new solar projects distributed throughout the metro area. 

Phase one of the project will add 21 MW of capacity across the Gratiot Findlay, Van Dyke/Lynch, and State Fair neighborhoods. Lightstar Renewables was selected to develop 10 MW of the portfolio. Site maps can be found here. 

Under the agreement, the solar facilities will be operated for 25 to 35 years. When the arrays reach the end of their useful life, the contract calls for developers to remove the equipment and return the property to a green field.

A coalition of local nonprofits, environmental groups, energy experts and solar developers are participating in the program. The groups engaged in a several-months-long community engagement program to explain its benefits and reach residents. 

Projects are planned in mostly vacant neighborhoods. Residents located in the footprint of the proposed solar facilities are offered compensation equal to double the market value of their property (or $90,000 minimum) along with moving expenses and relocation services. Renters will receive 18 months’ worth of rent and relocation services. The initiative includes energy efficiency upgrades for surrounding homes, with a minimum value of $15,000 on average per home. 

Each acre contributed will be provided with up to $25,000 in community benefits for energy-efficient upgrades, prioritizing affected homeowners and renters within the solar array footprint. Neighbors can elect to install energy bill saving measures like new windows, roof repairs, energy efficiency, home insulation, smart thermostats, battery back-up, and residential solar panels. 

For the next steps, the Office of Sustainability, The Department of Neighborhoods, the program’s Neighborhood Solar Partners and the solar developers to work with the community and get their insight into how the sites will look and operate. There will be a negotiated and approved agreement between the developer and residents, which will include what the design, vegetation and maintenance will be for each solar neighborhood before any construction work begins. 

List of Neighborhood Solar Partners: 

Green Door Initiative  

EcoWorks  

D2 Solar  

MI Interfaith Power and Light  

Peace Tree  

Sustainable Community Farms  

Walker-Miller Energy  

Rescue MI Nature  

Manistique Community Treehouse Center  

Ryter Cooperatives  

First Family Solar  

Anti-Gravity, LLC  

SDEV  

Energy Alliance 

From pv magazine 6/24

Tariff and trade tensions, tempered by favorable industrial policies courtesy of the US Inflation Reduction Act (IRA), have prompted multiple solar and storage manufacturers to announce plans to set up facilities in the United States, some for the first time.

To date, most firms eyeing US ventures are in China, reflecting the global dominance of Chinese PV and storage companies. Companies based in India are in the mix, too, followed by European producers and a roster of businesses from across Southeast Asia and South Korea.

With all this interest comes the realization that many business practices that are considered normal in the United States, differ – sometimes in big ways – from other parts of the world. Take employee parking, for example. Companies based in parts of the world where private vehicle ownership is not the norm may look at the acres of car park space at US manufacturing sites and see wasted potential.

On the other hand, some non-US employers are surprised when they hear worker dormitories are not standard at manufacturing sites. Or that the open labor market, not a government ministry, is the primary source for workers. Some find it a foreign concept that most Americans are willing to commute a significant distance to a job they secured on their own.

Other cultural differences include the layers of decision-makers who need to sign off on manufacturing plants, the subtle differences between product and equipment standards, and the emergence in some parts of the United States of opposition to any investments by Chinese companies.

Location and equipment

Site selection provides another challenge. Many available buildings were originally built for warehouse or distribution purposes. Such operations typically use little energy, at least when compared with solar and battery production lines. Electrical service upgrades often become necessary, with upgrades sometimes required all the way to the substation. In other cases, new substations need to be built from scratch.

That means the prospective manufacturer must work with local utilities to secure upgrades. Sometimes this can be done relatively quickly, with the utility able to locate transformers within a year.

However, equipment acquisition often proves more difficult. In the case of transformers and related substation equipment, wait times of several years are becoming more common. That means a non-US manufacturer needs to be something of a utility expert, able to understand and work not only across multiple business types (investor-owned, cooperative, municipal, and so on), but also with regulated or unregulated regimes which vary by state.

Even when it comes to commonplace equipment such as a facility’s air conditioner, lead times of two to three years are increasingly reported for 40-ton units and larger. Fewer than a dozen suppliers exist that manufacture equipment of this size for the US market and each typically produces only a handful of units each week, to meet global demand.

Matter of standards

Even for European companies, different quality, certification, and manufacturing standards need to be addressed. That’s because companies working in the European Union typically are more familiar with the bloc’s CE mark for health, safety, and environmental protection. Products that have received the CE mark are not automatically UL (Underwriters Laboratories)-listed for sale in the United States. In part, this is because some product types with the CE mark do not have to be third-party certified and are not necessarily compliant with US standards.

Rarely does a one-to-one equivalency exist so qualification testing often needs to be performed for European products and equipment to be used in the United States.

A further layer of complexity often exists here. The certification must satisfy not a federal or state official but, in many cases, an official as local as a fire marshal. These local code administrators are instrumental in deciding whether every aspect of a facility complies with a host of safety standards. Only after a fire marshal signs off can a manufacturing plant be occupied and begin production.

Multiple logistical issues can also surprise non-US firms. For example, an industrial site in the middle of the country might look like an ideal solution and then be rejected because it is too far from a deepwater port, which adds to transportation expenses and delays. Or an industrial site close to a deepwater port on one of the coasts may have an unacceptably large risk of suffering natural disasters such as hurricanes and floods. A site in the fast-growing and sunbaked Southwest of the United States may lack access to long-term, reliable water supplies.

Managing differences

Any company looking to base itself in the United States should develop a set of qualifying categories that rank the importance of a range of inputs, from available real estate to utility service upgrades to workforce availability, as they pertain to specific projects.

One outcome of such an exercise is that it’s rare for two seemingly similar businesses to favor the same site, let alone the same state. While many factory projects look the same from the outside, their specific needs can be quite different. One emerging factor is the policy – written and unwritten – in some states that discourages Chinese-owned factories. There are still states that welcome Chinese ownership, however.

At the federal level, there is the No Official Giveaways of Taxpayers’ Income to Oppressive Nations (NO GOTION) Act. This is a bill in the House of Representatives that would prohibit companies affiliated with certain regimes around the world from benefiting from IRA tax credits. It is likely that companies that have begun manufacturing prior to the bill’s passage will be affected differently.

Renewed interest in, and support of, domestic US solar manufacturing is opening attractive opportunities for foreign-based companies to set up production lines. Cultural differences exist, however, and need to be proactively addressed to help ensure a project’s profitability.

About the author: Mark Hagedorn is the vice president of manufacturing services for Clean Energy Associates.

Basis Climate has delivered an investment tax credit (ITC) transfer worth $600,000 for a 1.2 MW solar project, complete with a twelve-page transfer agreement plus requisite due diligence documentation. This transaction, facilitated under the new provisions of the Inflation Reduction Act (IRA), signals a significant shift in the tax credit landscape, expanding access to smaller-scale solar projects.

Tax equity, a financing arrangement where investors fund solar power projects in exchange for federal tax benefits like investment tax credits, is a complex field that integrates capital and labor. Initial costs for assembling these deals can start under $100,000 but may quickly escalate to millions. These expenses, covering fees for lawyers, accountants, and engineers, support extensive review of data rooms and the drafting of extensive contracts, focusing on compliance and diligence. The objective is to ensure that large investment groups can safely deploy billions of dollars in compliance with the U.S. Internal Revenue Service regulations.

The introduction of the IRA brings about ITC transferability. This mechanism provides a less formal alternative to traditional tax equity, facilitating the use of solar ITCs by investors.

When pv magazine USA consulted tax equity professionals, now also working with transfers, at the Solar Energy Industries Association’s annual Finance, Tax, and Buyer’s Seminar in March about the potential for simpler “six- to eight-page” tax transfer contracts, their response was a mix of skepticism and amusement. Such brief documents would stand in stark contrast to the extensive documentation required for solar tax equity transactions due to their complexity and regulatory demands. Our sources indicate that shorter contract lengths would align better with those used in the movie industry, which also navigates its own tax credit processes.

In the past, even the smallest projects that attracted tax equity investors required $1 to $2 million in tax benefits to offset the $75,000 in fees. That landscape is now evolving.

Source: Basis Climate’s online portal

Basis Climate, an internet-based tax credit transfer platform, has closed nearly $250 million in deals and boasts a $2 billion pipeline across various technologies, including solar, energy storage, renewable natural gas, wind, and electric vehicle charging. Over the past month, the company has managed over $50 million in term sheets and offers, with more than $70 million in signed deals progressing towards closure.

WeWould Solar, a single-purpose entity providing ancillary power to on-site agricultural processing in Gainesville, Florida, partnered with Basis Climate on the $600,000 ITC sale. The project is for a net-metered, behind-the-meter solar power initiative within the utility region managed by the Clay Electric Cooperative. The transaction took place through Basis Climate’s website, with the ITC being acquired by Creditable Capital.

Derek Silverman, co-founder & chief product officer at Basis Climate, shared insights with pv magazine USA.

The project is slated for development in three phases, each anticipated to be 1.2 MW. Notably, since the initial phase was under 1 MWac, it was exempt from prevailing wage or apprenticeship requirements. The installation will use SMA Sunny High Power PEAK3 inverters, Canadian Solar bifacial BiHiKu 425 W modules, and TerraSmart’s Glade Wave racking.

Source: WeWouldSolar energy monitoring dashboard

Creditable has disclosed that it is underwriting ITC transfer transactions targeting a 10% to 15% return on investment, net of fees and expenses, for its investors. For a $600,000 transaction, with limited information available, a return in this range suggests that Creditable Capital paid approximately 85 to 87 cents on the dollar. This payment rate is at the lower end of the typical industry range, where 90 to 95 cents on the dollar is common for larger solar power projects involving investment-grade asset owners and sophisticated development and construction firms.

First Solar, meanwhile, received 97 cents on the dollar when it sold its manufacturing tax credits.

Risk management

Silverman highlighted that the project’s diligence covered approximately 20 key areas, including organizational documents, project design, construction plans, operational strategies, insurance placement, and project valuation and qualification. Finalizing these core areas early helped Creditable Capital concentrate on higher-risk aspects, such as determining the project’s eligible basis and mitigating recapture risks, which involve the risk of having to return tax benefits if the project fails to comply with regulatory requirements.

For projects where asset owners lack strong financial foundations, buyers commonly secure tax insurance to safeguard against recapture risk. This insurance also provides a financial safety net, known as a backstop indemnity, in case the project’s liabilities exceed its assets. In the case of Creditable, the financial guarantees provided by the asset owner were sufficient, eliminating the need for tax insurance. However, when sellers lack a robust balance sheet, buyers generally obtain tax insurance to ensure comprehensive protection.

Adam Stern, founding partner of Creditable Capital, commented on their funding strategy, stating:

Creditable is getting more comfortable with the funding at a point in time after diligence is completed with a holdback for the IRS registration. Creditable, through its investors and financial institution relationships, is working to provide bridge loans on projects that it is buying the credits for.

A lingering risk in these transactions is how the IRS will require buyers and sellers to verify aspects of the deal, such as the determination of the basis.

Determining the appropriate ITC is a complex process due to the US Internal Revenue Service’s (IRS) detailed and evolving definitions of what constitutes an eligible project ‘basis’. For example, essential infrastructure like fences and roads, required by code for project deployment, are not considered part of the eligible basis, thus not qualifying for the 30% ITC. Similarly, interconnection costs had been excluded until recent changes under the IRA, which now allows projects under 5 MWac to include these costs in their ITC calculations.

In the traditional tax equity market, buyers of ITC needed to demonstrate significant involvement in the solar projects, taking on considerable operational and developmental risks, and ensuring long-term revenue from the projects flowed to them through complex financing arrangements. Some of requirements have been relaxed, although thorough due diligence and responsible investment practices remain essential.

A community solar project developed by Wunder Power in Maryland, part of an ITC sale facilitated by Basis in 2023. Image: Basis Climate.

From pv magazine Global

From pv magazine Germany

Meyer Burger’s new plant in Goodyear in Arizona passed the factory audit according to UL test standards without any deviations, and production can begin.

The solar cells required for module production have been delivered from the German site in Thalheim to the U.S. plant for some time now. This will continue to be the case in the future to ensure the ramp-up in the USA, Meyer Burger added.

In addition to the module factory, Meyer Burger also plans to build a cell factory in Colorado. It is not yet entirely clear when this will be able to start production. This depends on the conclusion of the 45X financing. The due diligence of a major U.S. bank on monetization in accordance with Article 45X of the Inflation Reduction Act (IRA) has been completed and negotiations on the loan agreements are currently underway.

Meyer Burger says it is aiming to complete the deal and make the payment by the middle of the third quarter. At this time, the payment of export financing by a German bank for the construction of photovoltaic production in the U.S. is also expected. The photovoltaic company has also submitted the final application for the loan from the U.S. Department of Energy to finance the cell factory. This is currently still being reviewed, says Meyer Burger.

In addition, a commercial agreement has already been negotiated with a U.S. industrial and technology group and a term sheet for a possible investment in Meyer Burger has been exchanged. This strategic cooperation would enable Meyer Burger to manufacture solar modules in the U.S. with an ever-increasing proportion of domestic components.

Meyer Burger has already signed several contracts with EPC companies and energy suppliers for the purchase of its solar modules manufactured in the U.S.. Now another purchase contract for up to 600 megawatts per year has been added with a large energy company from the U.S.. Delivery has been agreed for three years from 2026 with an extension option for two years. The agreement is to take effect when the financing of the solar cell plant in Colorado Springs is completed, Meyer Burger said.

Meyer Burger shut down its module plant in Freiberg, Saxony , in April after there was no agreement within the federal government on resilience measures for German and European photovoltaic manufacturers .

Maine may design a distribution system operator to advance distributed energy resources Maine has hired a consulting firm to evaluate whether forming a distribution system operator could speed deployment of distributed energy resources and support other state goals. Consultants are reviewing how the approach is used in five other countries.

New platform vets residential solar salespeople An industry plagued by deceptive practices is now verifying salespeople via a platform called Recheck.

Summit Ridge to procure 800 MW of Qcells solar panels The recent agreement brings the total to 2 GW of solar modules that the community solar specialist will purchase from Qcells, mostly manufactured in its facility in Georgia.

More solar installations coming to U.S. military bases In a partnership with Duke Energy valued at an estimated $248 million, the U.S. Department of Defense will be the exclusive purchaser of all output generated by two new solar facilities, which will serve five military bases.

Siting solar projects for best environmental results A new white paper from Clearloop identifies key U.S. regions for best carbon displacement impact of new clean energy projects.

Top solar panel brands in reliability, quality, and performance Solar modules are evaluated in the Renewable Energy Test Center annual PV Module Index.

pv magazine interview: ‘In the next year, some of these guys are going to be bankrupt’ At Intersolar in Munich, pv magazine spoke with Jenny Chase, solar analyst at BloombergNEF, about the incredibly low polysilicon prices, massive overcapacity, and increasing consolidation. According to Chase, this year there will be enough polysilicon capacity to produce 1.1 TW of solar modules, but global module demand is expected to reach around 585 GW. 

The Renewable Energy Test Center (RETC) released its 2024 PV Module Index report, evaluating the reliability, quality, and performance of solar panels.

Solar modules are put through a variety of accelerated stress tests to evaluate these parameters. Through comparative test results, project stakeholders can select products best suited for a particular environment, location, or portfolio.

To identify the best of the best, RETC reviewed and ranked the overall data distributions across three disciplines: quality, performance, and reliability. Find the overall top performers at the end of this report.

Reliability

Backsheet ultraviolet durability

Top performers: JA Solar, Longi Solar, SolarSpace

Backsheet ultraviolet durability (BUDT) incorporates a durability testing sequence to probe glass-on-backsheet PV module designs for vulnerabilities to UV exposure and prevent backsheet-related failures. This BUDT sequence starts with 1,000 hours of damp heat exposure to weaken polymeric bonds.

Highlighted top performers experience no backsheet cracking in the test.

Damp heat test

Top performers: Astronergy, ES Foundry, Longi Solar, Runergy, and Trina Solar

The RETC thresher test includes a damp heat test that exposes modules for 2,000 hours, double the amount required for product certification. The test evaluates a module’s ability to withstand prolonged exposure to humid, high-temperature environments. Taking place inside an environmental chamber, the test exposes modules to a controlled temperature of 85 C (185 F) and a relative humidity of 85% for a set amount of time.

RETC highlighted performers that experienced less than 2% degradation after this exposure.

Hail durability

Top performers: JA Solar, Longi Solar

RETC’s hail durability test takes UL and IEC standards testing a step further, exposing solar modules to higher kinetic impact to reflect the risk posed by hail over a 25 or 30-year operating life. In addition to ballistic impact testing, RETC runs thermal cycle and hot-spot tests to reveal potential long-term module degradation.

The top performers in this category withstood an effective kinetic energy of 20 Joules or more. These modules effectively demonstrated resistance to a 45 mm (1.8 in.) iceball traveling at a terminal velocity of 30.7 m/s (68.7 mph).

Potential induced degradation (PID) 

Top performers: Astronergy, ES Foundry, GEP VN, Gstar, JA Solar, Longi Solar, Qcells, REC Solar, Runergy, SEG Solar, Silfab Solar, SolarSpace, Talesun, Trina Solar, VSUN Solar, and Yingli Solar

Potential induced degradation (PID) resistance tests rack-mounted modules in an environmental chamber, which controls temperature and humidity and exposes them to a voltage bias of several hundred volts with respect to the mounting structure for 192 hours (PID192 exposure). PID testing characterizes a module’s ability to withstand degradation due to voltage and current leakage resulting from ion mobility between the semiconductor and other elements in module packaging.

RETC required that PV module models withstand PID192 exposure with less than 2% degradation in maximum power. At the other end of the spectrum, it considered maximum power degradation greater than or equal to 5% a red-flag result.

Static and dynamic mechanical load test

Top performers: Aptos Solar, Astronergy, ES Foundry, Gstar, JA Solar, Longi Solar, Runergy, Silfab Solar, SolarSpace, Trina Solar, and Yingli Solar

This test exposes modules to 1,000 cycles of +1,000 pascal and –1,000 pascal loads at a frequency of three to seven cycles per minute. Measurements were taken after this stress test rate electrical performance.

This year, RETC required that PV module models withstand SDML exposure with less than 2.5% degradation in maximum power. It considered maximum power degradation greater than or equal to 5% to be a red-flag result. In this testing category, it notes that 68% of samples qualified as high achievers whereas 7% returned red-flag results.

Thermal cycling

Top performers: Aptos Solar, Astronergy, ES Foundry, Gstar, JA Solar, Longi Solar, Qcells, Runergy, SolarSpace, Trina Solar, and Yingli Solar

The thermal cycle test calls for cycling modules in an environmental chamber between two temperature extremes—85 C (185 F) on the high end and –40 C (–40F)  on the low end. The RETC test runs 600 cycles, three times as much as the 200 required for certification.

About 67% of modules in this test achieved high performer status of less than 2% power loss, while 9% of tested brands had power losses of 5% or more.

Ultraviolet induced degradation (UVID)

Top performers: Trina Solar and VSUN Solar

UVID tests characterize a PV module’s ability to withstand ultraviolet induced degradation. This optional testing sequence exposes test samples to 220 kWh/m2 of UV exposure (UV220), nearly 15 times the UV exposure required for product certification.

Top performers withstand UV220 exposure with less than 2% degradation in maximum power. Red flag modules that degraded more than 5% represented 40% of brands tested.

“Alarmingly, we observed double-digit power loss in some mass-produced, commercially available PV modules, indicating that these products could degrade 10%–16% in the first three years of in-field operation,” said RETC.

Performance

Module efficiency

Top performers: Astronergy, Mission Solar, Qcells, REC Solar, and Silfab Solar

Module conversion efficiency is determined by dividing a product’s nameplate maximum power rating under standard test conditions by its total aperture area.

RETC has recognized manufacturers of PV module models with conversion efficiencies greater than 21% as test category high achievers. About 56% of tested modules were listed as high performers.

Incidence angle modifier

Top performers: Dehui Solar, ES Foundry, JA Solar, JinkoSolar, Longi Solar, Meyer Burger, Qcells, Runergy, Silfab Solar, and SolarSpace

Incidence angle modifier (IAM) is a performance characteristic that accounts for changes in PV module output based on changing sun angles relative to the plane of the array. To characterize IAM, RETC conducts electrical characterization tests at different incidence angles, ranging from 0° to 90°.

Manufacturers of PV module models with an IAM greater than 88% at a 70° angle of incidence were listed as test category high achievers.

LeTID resistance

Top performers: Astronergy, Gstar, JinkoSolar, Longi Solar, Runergy, SEG Solar, Silfab Solar, SolarSpace, Talesun, Trina Solar, VSUN Solar, Waaree, Yingli Solar

Relatively new cell technologies may experience long-term degradation associated with light exposure and elevated temperatures. This phenomenon, called light- and elevated temperature-induced degradation (LeTID), is tested with a protocol of light soaking, followed by 75 C (167 F) temperature exposure for two 162-hour cycles to identify significant degradation (>5%). Subsequently, test samples are subject to 500 hours of 75 C temperature exposure followed by two additional 162-hour cycles.

Highlighted top performers demonstrated products that had less than 0.5% power loss after 486 hours of exposure.

LID resistance

Top performers: Astronergy, GEP VN, Gstar, JA Solar, JinkoSolar, Longi Solar, Meyer Burger, Qcells, Runergy, SEG Solar, Silfab Solar, SolarSpace, Talesun, Trina Solar, VSUN Solar, Waaree, and Yingli Solar

Light-induced degradation (LID), or power losses from sunlight exposure, affects some PV cell types but not others. PV modules exposed to LID losses rapidly lose performance over the first few hours or days of operation before stabilizing. RETC notes LID resistance is highly correlated with cell type.

RETC required that PV module models withstand the LID sequence with less than or equal to 0.5% degradation in maximum power.

Module efficiency

Top performers: Auxin Solar, JA Solar, Longi Solar, Meyer Burger, Mission Solar, Qcells, REC Solar, Silfab Solar, Trina Solar, Yingli Solar

Module efficiency, or the percentage of incident solar energy converted to electrical energy, is a well-known and key metric for solar performance. It is highly correlated with cell technology and module design.

The top 14 highest scoring modules scored efficiencies of 20% or more. An n-type TOPCon cell scored the highest at 25.8% efficiency, followed by a monocrystalline silicon module with heterojunction technology, recording a 22.4% efficiency.

PAN file

A recent report by Tennessee-based carbon solutions platform Clearloop noted that private companies have contracted for 71 GW of new renewable energy capacity in the U.S. since 2014, which is enough electricity to power nearly 15 million homes. However, the distribution of solar and wind projects tends to cluster regionally, and not only because of the availability of wind and solar resources. State and utility renewable energy policies play a huge role in where new projects are sited.

Clearloop, which is a subsidiary of solar power producer Silicon Ranch, partnered with non-profit emissions data analysis firm WattTime to study how renewable energy projects – and solar in particular – could be sited to produce better environmental and even social outcomes. The resulting white paper, Curing Carbon Blindness, reinforces the important role of private sector action in growing renewable energy in the U.S. while at the same time saying such action can be better focused to achieve decarbonization goals.

By incorporating the principle of “emmissionality,” the report suggests, companies looking to purchase renewable energy credits (RECs) or offset to their carbon footprints should seek to contract with solar and wind projects in regions with the highest percentage of fossil fuel generation.

Under the current structure, all RECs are essentially created equal, meaning an offtaker in one part of the country can buy RECs from a project anywhere else. There are differences in regional markets, such as ERCOT, but this is generally how it works. Laura Zapata, co-founder and CEO of Clearloop and one of the authors of the carbon blindness report, said not all MWh of clean energy are created equal in terms of their environmental impact.

“We still get over 60% of our electricity in this country from fossil fuels,” Zapata told pv magazine USA. “And so, our goal is how do we build more solar projects in the most carbon intense communities, which also happen to be often the most underserved and disadvantaged communities.”

Unlike most countries, the U.S. does not have a single national energy grid. It is more like a continent with many regional grids of widely varying emissions characteristics. Some regions, such as California, have grids with high percentages of renewables, while others, such as in the southern Appalachians, have fossil-fuel-heavy generation.

According to the Clearloop report, turning on a light switch in eastern Kentucky will result in 54% more carbon emissions than turning on a corresponding light in Los Angeles. This same data show that a new solar plant located in eastern Kentucky will reduce emissions by 62% more than the same plant would in Los Angeles.

By combining historical irradiance data with WattTime’s marginal emissions data, Clearloop says it is able to model not only how much electricity a solar project is expected to supply the grid, but also the marginal carbon intensity of the power generation sources it is displacing in that region at specific times.

Zapata argues that the marginal difference in emissions that results when solar generation displaces fossil fuel generation should be a key factor in citing projects. Using WattTime’s emissions analysis methodology, Clearloop had identified the regions of the U.S. where new solar, the report’s main focus, would have the greatest decarbonization impact by reducing a like amount of fossil fuel generation sources.

The analysis also extends to voluntary carbon offset markets that rely on private carbon credit registries, such as Verra or Gold Standard. This enables a company to use the methodology for contracting with solar projects to offset its carbon footprint from activities other than electricity consumption, such as air travel.

“Our clients are not interested in the electricity,” Zapata said. “What they want is credit for the environmental impact of those electrons flowing into the grid. So, whether they count them as RECs or offsets, we’re sort of agnostic.”

With more than 300,000 buildings and 600,000 vehicles, the U.S. Government is the nation’s largest energy consumer. As a part of the Federal Sustainability Plan that directs the Government to achieve net-zero emissions by 2050, the Government is quickly ramping up use of solar energy at military bases, five of which will soon be drawing electricity from two solar installations in South Carolina.

In a partnership with Duke Energy valued at an estimated $248 million, the Department of Defense (DOD) will be the exclusive purchaser of all output generated by two new solar facilities. The five military installations across North Carolina and South Carolina to benefit from the clean energy include Fort Liberty, USMC-Camp Lejeune, USMC-Cherry Point, USAF Seymour Johnson and USAF Shaw.

“DoD is leading by example on climate change in ways that will spur new clean electricity production, create good-paying jobs, increase our resilience to climate change, and enhance our national security,” said Andrew Mayock, Federal Chief Sustainability Officer at the White House Council on Environmental Quality.

Duke Energy estimates that it will provide 135 MW and approximately 4.8 million MW-hours of renewable energy in both states over a 15-year delivery period. According to the DoD, these installations will achieve 75% of their 2030 carbon-free energy requirement. Fort Liberty, for example, will reduce its emissions from electricity by 27% compared to 2022, with cost savings possible by 2040. The two solar facilities, which are expected to become operational in 2026, will be developed, owned and operated by energyRe, according to Duke.

“This project is a great opportunity to assist our military departments and our warfighters in their decarbonization goals and is paramount to reaching our initial goals of Executive Order 14057, Catalyzing Clean Energy Industries and Jobs Through Federal Sustainability. DLA Energy is committed to supporting the administration’s clean energy initiatives and helping the military services and whole-of-government partners achieve their climate change goals,” said United States Air Force Col. Jennifer Neris, director of carbon pollution-free electricity for the Defense Logistics Agency.

Duke Energy reports that it currently owns, operates and purchases more than 5,100 MW of solar power on its energy grid in the Carolinas or enough to power nearly 1 million homes annually. North Carolina currently ranks No. 5 in the nation for overall solar power. With a portfolio of nuclear, hydro and renewable energy, the utility says more than half of its energy mix in North Carolina is carbon-free.

The DoD said in a statement that it will continue to seek partnership opportunities that enable the agency and other Federal partners to achieve President Biden’s carbon-free energy goals and build a robust, clean, and domestically based electricity supply chain by 2030.

“Our partnerships with utility companies are essential to delivering energy resilience for the Army,” said Rachel Jacobson, assistant secretary of the Army for Installations, Energy, and Environment. “These partnerships are helping us put microgrids with carbon-free energy generation and storage on our installations. And our continuing collaboration with Duke Energy allows the Army to contribute to a more reliable commercial grid that strengthens the resilience of the defense communities where our soldiers, military families, and civilians live. I am proud of these partnerships and look forward to expanding them so that our installations always have access to the electricity we need to defend the nation.”

Summit Ridge Energy expanded its partnership with Qcells with an agreement to purchase 800 MW of solar panels.

The agreement builds on an existing 1.2 GW relationship between Qcells and Summit Ridge, announced in April of 2023 by Vice President Kamala Harris. At the time the 1.2 GW order was the largest equipment purchase in history for the community solar market.

By increasing the total commitment to 2 GW, Summit Ridge reports it will develop more than 100 additional community solar projects across the country using U.S.-made solar.

Last year Qcells announced what was then the largest investment in U.S. solar manufacturing history, investing more than $2.5  billion to build a complete solar supply chain in the United States. This made the Korean company, a subsidiary of Hanwha Solutions, the first company to establish a fully-integrated silicon-based solar supply chain in the U.S. When complete, Qcells solar panels — from polysilicon to the finished panel — will be entirely made in the U.S.

Both the build-out of Qcells U.S. manufacturing footprint and the growth of Summit Ridge Energy are incentivized by the Inflation Reduction Act (IRA). The includes tax incentives for domestic energy production as well as manufacturing. Many of Summit Ridge’s solar projects also qualify for IRA tax credits that will provide thousands of low-income households with greater access to clean energy savings.

“We are excited to expand our partnership with Qcells, which enables Summit Ridge to deliver on our promise of giving more Americans the opportunity to power their homes and businesses with locally generated clean energy,” said Brian Dunn, chief operating officer of Summit Ridge Energy. “Through our Qcells partnership, we are able to support domestic manufacturing and job creation, while simultaneously bringing low-cost clean energy to communities that have historically been left out of the clean energy transition.”

Summit Ridge’s planned fleet of community solar farms are expected to generate enough clean energy to power an estimated 200,000 homes and businesses. Since launching in 2017, the company reports that it has deployed over $2.6 billion into clean energy assets and controls a development pipeline of more than 3 GW that will provide solar power to homes and businesses nationwide.

“Expanding this relationship with Summit Ridge Energy means more communities will have access to the most affordable energy resource in the world,” said Justin Lee, CEO of Qcells. “This partnership not only supports the domestic manufacturing industry and thousands of jobs in solar, but it also ensures more people – especially those who have historically been left out – benefit from everything the clean energy economy has to offer.”

The majority of the solar panels purchased by Summit Ridge will be produced in Qcells’ new U.S. manufacturing facility located in Georgia. Additionally, Qcells will continue to provide Summit Ridge with battery storage and software solutions under separate procurement agreements.

Leading residential solar industry financers and the Solar Energy Industry Association (SEIA) are partnering with the newly launched Recheck, a platform designed to create a registry of residential solar salespeople and vet their conduct.

Residential solar has long struggled with aggressive sales tactics that has led to negative customer experiences. Many installers outsource their sales efforts to a third party, which can create a disconnect between sales promises and installation realities.

The platform was launched by a consortium of the main players in U.S. residential solar finance, including Dividend Finance, Freedom Forever, GoodLeap, Mosaic, Palmetto,  Sungage Financial, Sunlight Financial, and Sunrun.

“A healthy solar industry is vital to consumers and the U.S. energy transition. Recheck is proud of its founding partners and is committed to building the tools to ensure long-term trust with consumers,” said Tim Trefren, Recheck co-founder and CEO.

Recheck creates an online registry of approved solar salespeople, issuing a Recheck ID that allows contractors, financiers, and technology platforms to confirm that their sales partners meet certification, licensing, and training requirements.

The platform marks a first-of-its-kind opportunity for solar finance, contractor, and technology partners to track sales conduct across the industry.

Recheck will also facilitate industry-wide data exchange across the platform. The data will businesses vet sales partners, prevent poor practices by unregistered salespeople, and identify individuals with a history of consumer protection violations that move from company to company.

“Solar remains America’s most popular form of energy and will be installed on 10 million homes by 2030. It’s our job to make sure the solar and storage industry is accountable to the millions of families that are putting their trust in us to power their lives,” said SEIA president and chief executive officer Abigail Ross Hopper.

Recheck founding partners will be part of an ongoing advisory board and have committed to driving the adoption of Recheck IDs within their platforms in 2024 and beyond.

Along with supporting the launch of Recheck, SEIA is developing industry wide standards for residential solar, with accreditation from the American National Standards Institute. SEIA is proactively tackling issues that build confidence among customers, regulators, investors, rating agencies, and other stakeholders. These standards will contribute assurance that solar and storage systems have been ethically, sustainably, and responsibly sourced, manufactured, transported, installed, operated, and recycled.

In Europe, there are still large stocks of modules produced in 2023, or earlier with distributors and installers themselves. If these have the smaller dimensions commonly used for rooftop systems in Germany, they are selling poorly due to low power output classes. Building owners usually want to see a high wattage and the latest technology installed in their systems, which makes it much more difficult to sell existing inventory.

Despite the supposed reduction in module production, and European import volumes, it appears that more Asian panels are still reaching the European market than are currently in demand. This, in turn, is causing inventories to grow, even in high-performance classes, exerting additional pressure on module prices, especially on old modules which were produced and purchased at significantly higher prices.

The ability to devalue old stock varies greatly from company to company, resulting in vastly different prices for modules with passivated emitter rear contact (PERC) cell technology. The overall price differences between model categories is shrinking.

Shelf warmers

It is very difficult to get rid of these older modules in markets outside Europe without accepting a massive loss in value. Africa and Southeast Asia are also likely to be oversaturated with modules and Chinese-made products cannot easily be sold to the US market. One strategy that is becoming increasingly established is to enable concessions in the soft factors of the trade business. There can be some room to move in payment and delivery terms. Instead of offering the modules at a lower price, a credit line is granted – often without requiring collateral – and delivery can be offered for free. That said, it is doubtful that this tactic will work over the long term. Many smaller companies are on the brink of insolvency and the possibility of defaults cannot be ruled out. The pressure to sell should, therefore, not override common sense and tempt providers to take incalculable risks.

Some suppliers are also attempting to take refuge in online marketplaces where they hope to sell quickly to international customers without incurring sales and marketing costs. However, the competitive pressure there is also high and the goods can often only be sold at dumping prices.

Online business models come with further risk. They seldom provide solid opportunities to get to know the potential business partner in advance – sellers just take what they can get. Misunderstandings can arise in business transactions, especially across national borders and the platform operator is not always available to provide support and advice. The effort involved in an online transaction can quickly become greater than buying or selling within an established business relationship. Everything can go smoothly but that does not necessarily mean that it will.

Notes: Only tax-free prices for PV modules are shown, with stated prices reflecting average customs-cleared prices on the European spot market. Source: pvXchange.com

Project sales

One possibility for making good use of surplus old solar modules is to install them in larger open-space projects or rooftop systems. Smaller formats may not be a bad choice in areas with higher wind or snow loads. Although the material and installation costs increase slightly, easier handling during installation makes up for this disadvantage. There is another undeniable advantage here – that the modules are already in stock. This guaranteed availability means there can be no ­delivery problems and therefore no delays in the construction process. Add in a few unsold inverters and cable reels and the components are in place for a working PV system.

Once a system has been installed and connected to the grid, nobody will care whether the solar modules belong to the very latest generation or not. The resulting asset can then be marketed better than the 400 W PERC modules in the current market situation. This can also be done via an online brokerage portal, for companies not yet properly set up for project sales.

About the author: Martin Schachinger has a degree in electrical engineering and has been active in PV and other renewables for almost 30 years. In 2004, he founded online trading platform pvXchange.com, enabling wholesalers, installers, and service companies to buy solar panels, standard components, and inverters that are no longer manufactured but which may be urgently needed to repair defective PV plants.

Maine has hired the consulting firm Strategen to evaluate whether a distribution system operator (DSO) could be designed to achieve growth in distributed energy resources and help the state meet other goals: lower electricity costs, improved electric system reliability, and the state’s overall climate goals.

The state law calling for the study defines roles for a DSO including overseeing integrated system planning, operating the state’s electric grids, and administering a market for distributed energy resources (DERs).

Speaking on a webinar about the study, Strategen Advisor Matthew McDonnell said the firm will evaluate the potential to reduce customers’ electric bills by first considering the “base case” for the state of Maine—that is, investment priorities that have already been established through integrated resource planning or other means. The firm will then “look at how a differentiation from that base case to more of a high DER state, as facilitated by a prospective DSO, can enable some potential cost savings going forward through load flexibility and other opportunities.”

Responding to a question about distributed storage, McDonnell added “certainly we’re thinking about distributed energy storage and its use either as a standalone asset or in conjunction with distributed solar or other energy resources.”

Standalone distributed solar was not mentioned on the webinar, which was hosted by the Maine Governor’s energy office.

The energy office said in a statement that no jurisdiction in the U.S. now has a DSO. McDonnell said Strategen is “looking to draw learnings” from similar distribution network operator approaches used in parts of the United Kingdom, Australia, Germany, France, and Ontario, Canada.

If Strategen’s initial study concludes that a DSO can be designed to help achieve the state’s objectives, and the Governor’s energy office agrees with that conclusion, Strategen will conduct a second part of the study to develop a DSO design proposal that identifies the scope and characteristics of a DSO.

A DSO design “may not include the acquisition or ownership of any transmission and distribution utility assets,” the state law says. The law calls on the Maine governor’s energy office to ensure opportunities for stakeholder engagement throughout the study process.

The Strategen team includes consultants Lorenzo Kristov, who previously worked for California’s grid operator CAISO, and Mark Patterson, principal at Energy Catalyst in Australia.

Strategen expects the draft of its initial study to be released in late summer. If a second part of the study is authorized, that part is expected to be completed by year-end.

The nonprofit Clean Coalition, based in California, has advocated for the formation of distribution system operators in that state.

New York policy authorizes $814.6 million to fund energy storage The new order puts the state on track to install 6 GW of energy storage by 2030.

Utility-scale solar development: Good planning makes good neighbors A recent study by Berkeley Lab, the University of Michigan, and Michigan State University found that sharing plans for large-scale solar projects with local residents improves the perception of such sites.

GCL says perovskite solar module passes silicon degradation tests At Intersolar Europe, the Chinese manufacturer said the perovskite-silicon tandem module would cost 50% of a crystalline silicon module that costs $0.15 per W, meaning $0.075 per W.

A look at the prevailing wage and apprenticeship final rule Taxpayers seeking to claim the highest available investment and/or production tax credits for renewable energy projects must comply with the prevailing wage and apprenticeship requirements.

Spontaneous glass breakage on solar panels on the rise The National Renewable Energy Laboratory noted an increase in spontaneous glass breakage in solar panels. The PV Module Index from the Renewable Energy Test Center investigates this and other glass-related trends in solar manufacturing.

In case you missed it: Five big solar stories in the news this week  pv magazine USA spotlights news of the past week including market trends, project updates, policy changes and more.

Glass is a unique material used for its chemical stability and visual transparency. It is commonly used in solar panels as a protective outer layer.

In its annual PV Module Index, the Renewable Energy Test Center (RETC) examined emerging issues in solar glass manufacturing and field performance. It found reports of a concerning rise in solar panel glass spontaneously breaking in the field, sometimes even before commissioning.

Teresa Barnes, Ph.D., manages the Photovoltaic Reliability and System Performance Group at the National Renewable Energy Laboratory (NREL). Barnes and her colleagues at NREL reported the issue.

“Spontaneous glass breakage is an example of a failure mode that we didn’t used to see. When I first started working on solar module reliability seven or eight years ago, we mostly heard about glass breakage when there were sloppy operations and maintenance practices,” said Barnes.

Now, this is no longer the case, and the NREL reliability team is regularly receiving reports of glass breakage in silicon modules unrelated to direct damage from maintenance or storm impacts. The team found that over time, the average quality of solar glass appears to be decreasing.

“It used to be the case that modules would pass the IEC 61215 static load test with a big safety factor,” said Barnes. “Today, modules are either barely passing the base static load test or they are not passing with higher safety factors. Some new module designs are simply not passing the minimum static load test.”

The NREL team has begun to hypothesize that glass damage in solar panels is undergoing a similar process to a car windshield in need of replacement. When a windshield takes impact damage, often it only shows up as a small star-shaped mark that seems insignificant. But when extreme weather conditions with very high or low temperatures cycle through, the severity of the damage is fully realized, and suddenly a large crack is visible across the whole surface.

“We think a similar dynamic could be a root cause of spontaneous solar glass breakage,” said Barnes.

This rise in breakage is likely due to the trend solar glass getting thinner over time, said NREL. Mike Pilliod from Central Tension, who spoke at NREL’s 2024 PV Module Reliability Workshop said any manufacturer can temper glass that is 3 mm. But under 3 mm, glass tempering is a difficult process. He said that as glass gets thinner, it takes fewer defects to create strength-limiting flaws in the glass. These flaws are actively being studied by NREL to understand some of the potential pitfalls of using thin glass in solar manufacturing.

Barnes warned that it may be a combination of effects that are making glass breakage a larger threat that before. Modules are getting larger, frames are getting thinner, and mounting rails are getting closer together. All these factors lead to “large, floppy modules” that are putting more pressure on the glass surface, which is also getting thinner in many modules.

The NREL team said at this year’s PV Module Reliability Workshop, manufacturers began speaking about introducing thicker frames and wider mounting positions.

“As people better understand how the module system interacts, they can work to optimize how loads are balanced out,” said Barnes. “The pendulum in that balancing act may already be swinging back toward the integrity of the frame and the mounting rail.”

While some module providers are focused on frames and mounting, others have introduced tempered glass modules that are marketed as hail-hardened and resilient to extreme weather.

RETC asked Barnes about the recent catastrophic losses in Texas, where hailstorms caused hundreds of millions of dollars in damage to operational solar assets.

GCube Insurance, an underwriter for renewable energy, said despite being only 1.4% of total number of insurance claims filed, about 54% of incurred costs of total solar losses can be attributed to hail. This is based on data collected by Gcube over the past five years. Average costs totaled $58 million per claim.

“Ten years ago, people would run you out of the meeting on a rail if you mentioned climate-specific module designs. The consensus was that this would simply be too expensive,” said Barnes. “Now climate specific modules and climate-specific testing are starting to look viable because we are seeing more of an emphasis on total system costs. It is entirely possible that we could see hail-hardened modules, especially in a market like the United States, where it could be worth paying more up front for hail resilience.”

From pv magazine 6/24

Data centers come in many sizes. The largest, China Telecom’s Inner Mongolia Information Park, spans 100 hectares and consumes up to 150 MW per hour. North Virginia, in the United States, houses around 300 facilities in a grouping known as Data Center Alley, with each consuming about 10 to 50 times the energy per square meter of a typical commercial office.

Utility Dominion Energy was forced to pause grid connections for new members of Data Center Alley in 2022 and is now constructing new transmission lines to meet demand.

The United States has more than 5,000 data centers and consultant McKinsey & Company expects their power consumption to rise from a peak 17 GW/hour, in 2022, to 35 GW/hour in 2030.

Scaling up

Data centers are becoming more high density and power intensive but also more efficient.

“The hyperscale cloud providers all seem to be locked in an arms race to build out as much infrastructure as quickly as they can,” said Dan Thompson, principal research analyst at S&P Global Market Intelligence. “Some of this is high-density, high-performance, compute-type deployments, but a lot of it is also the cloud providers building out at scale. Densities in watts per square foot are rising, but I think what we’re seeing right now is just the tip of the iceberg.”

Data centers have a power usage effectiveness (PUE) ratio, which dictates how much energy is needed for computing versus other activity, such as cooling, lighting, and power losses. A PUE of 1.5 would indicate a data center requiring 500 kW of extra power for 1 MW needed for computing purposes.

S&P’s Thompson said power densities have fallen from an average 1.58 in 2020, as power density and cooling efficiency have risen. The lowest values, however, involve some trade-offs.

“The data centers we’re seeing built now are designed for PUEs of 1.3 to 1.4, so you can see some improvement there,” said Thompson. “That said, while they are designed for those PUEs, many factors could cause the building to never actually realize that PUE, depending on climate and operations. We have seen some constructions with a designed PUE of 1.15 to 1.2, however these facilities require the consumption of large volumes of clean water to reach those numbers. Given the issues around access to clean water, hyperscalers and the companies building data centers for them have tended to build slightly less efficient data centers for the sake of using very little or no water.”

Greener computing

The world’s technology giants are the biggest corporate power purchase agreement (PPA) buyers of renewable energy. On March 1, 2024, Microsoft and asset manager Brookfield signed a record 10.5 GW deal to deliver solar, wind, and “new or impactful carbon-free energy generation technologies” to Microsoft from 2026 to 2030.

Microsoft says its CO₂ emissions are now up 30% from when it set its 2030 net-zero target, in 2020, and mainly because of data centers.

“The rise in our scope 3 emissions [from third-party, supply chain companies] primarily comes from the construction of more data centers and the associated embodied carbon in building materials as well as hardware components such as semiconductors, servers, and racks,” said Microsoft, adding that the 10.5 GW renewables PPA is on top of a 19.8 GW clean power portfolio.

Simon Maine, managing director for communications, renewable power, and transition at Brookfield, told pv magazine that the deal was eight times bigger than any previous PPA.

“We have a very large renewable power and transition business, with over $100 billion of assets in that division alone, and 30-plus-years’ experience in the sector,” said Maine. “We look to either buy assets or, more recently and more likely, buy companies. The companies will have high-quality management teams that have a full spectrum of capabilities. We have projections to install somewhere between 5 GW and 7 GW per year [to 2030]. The deal with Microsoft probably covers about 30% of that growth and that’s without factoring in further acquisitions.”

Brookfield is reported to have acquired a majority stake in India’s Leap Green Energy for $500 million, and is also said to be preparing to acquire Australian renewable energy developer WindLab, which has around 24 GW of projects in development or under construction.

Anas Papazachariou, senior PPA manager at renewables developer Cero Generation, explained how colocation can meet data center energy demand.

“A single solution where solar meets the full increase from the growing number and size of data centers is probably not optimal and I have to be honest about that,” he said. “So a lot of the offtakers are looking to create virtual portfolios whereas wind and solar, and combined batteries, are part of their portfolio because they’re actually optimizing their profiles through that basis.”

Solar-plus-storage means more expensive energy offtake agreements, but reduced risk, said Papazachariou.

Efficient clusters

“Hyperscale” data centers are clustered for efficiency. Where latency is concerned, however, many other data centers, especially those serving internet and network services, are distributed closer to population centers. These are smaller and experience more variation in demand.

Mike Bates, general manager for the Intel Energy Center of Excellence, said data centers are using workload management software that can respond to real-time energy conditions. Intel is deploying software inside data centers to manage workflows and loads, while also tracking carbon footprints of workloads for audits by companies claiming low carbon or net-zero workflows.

“One of my customers is the [internal] Intel Data Center group and we work to deploy these same solutions we’re taking outside of the market, making sure that we’ve hardened data centers for climate impacts while opening up new opportunities as well,” said Bates. “For example, our software is also able to adapt workloads for certain conditions. If I can push a workload inside the data center to the times when energy is in surplus, I can actually get paid to consume that energy.” He added that energy resiliency also includes interruptions to supply, when considering climate impacts.

Ben Levitt – associate director for the gas, power, and climate solutions North American power and renewables research team at S&P Global Commodity Insights – highlighted the cost benefits of operating data centers with flexibility.

“Data centers with flexible operations – that is, interruptible, price-responsive – cost less to supply than ones that are less flexible,” said Levitt. “Data centers that are interruptible might even be able to get a faster grid connection. In addition, and separately, it is possible that big tech may drive investment in developing and scaling the new, ‘clean firm’ technologies needed for around-the-clock clean energy for their data centers.”

Levitt said new loads will lead to new renewables investment but fossil fuel generation, and increasingly batteries, will also pick up extra demand. Ultimately, a lot will depend on local bureaucracy and permitting.

Levitt added that it is possible big technology companies will play a role in scaling new clean technology. “These efforts could accelerate the development of newer technologies that could reshape energy supply mix at a faster pace than previously considered,” he said.

Nearly two years following passage of the Inflation Reduction Act of 2022 (IRA), Treasury and the IRS released the unpublished version of the final rule (Final Rule) for compliance with the IRA’s prevailing wage and apprenticeship requirements (PWA requirements).

Taxpayers seeking to claim the highest available investment and/or production tax credits for renewable energy projects must comply with the PWA requirements. A taxpayer must ensure that laborers or mechanics employed by the taxpayer or any contractor or subcontractor in the construction, alteration, or repair of a qualifying facility comply with the PWA requirements.

The Final Rule concludes the federal rulemaking process for the PWA requirements. (Note: The Final Rule is scheduled to be officially published on June 25, 2024, and therefore this article relies on the unpublished version.)

The Final Rule will replace the previously-issued Notice of Proposed Rulemaking (released August 30, 2023) (NOPR), which replaced the Initial Guidance (released November 30, 2022). Overall, the Final Rule is generally consistent with the NOPR, providing helpful clarification on industry concerns raised in comments to the NOPR. However, the Final Rule expressly declines to address industry-specific concerns, emphasizing that determinations of compliance with PWA requirements will be made based upon specific facts and circumstances. It therefore leaves several questions open to interpretation, including whether commissioning work is subject to PWA requirements and to what extent certain post-operational work may be subject to PWA requirements.

Clarifications

First, with respect to when PWA requirements apply, the Final Rule provides two useful clarifications:

Its supplementary information notes that “unrelated third party manufacturers who produce materials, supplies, equipment, and prefabricated components for multiple customers or the general public” are not subject to PWA requirements. In other words, most suppliers (absent performance of construction, alteration or repair on a project site) will not be subject to PWA requirements.

It also clarifies that apprenticeship requirements only apply to the construction of a qualified facility, and do not apply to alteration or repair of a facility after the facility is placed in service. In other words, most operations and maintenance vendors will not be subject to apprenticeship requirements.

Second, with respect to payment of prevailing wages, the Final Rule outlines regulations consistent with the NOPR: A taxpayer must ensure that laborers or mechanics employed by the taxpayer or any contractor or subcontractor in the construction, alteration, or repair of the facility are paid prevailing wages for the specific type of construction in the geographic area where the facility is located. The definitions of “laborers and mechanics” and “construction, alteration or repair” provided in the Davis-Bacon Act (40 U.S.C. § 3141 et. seq.) apply to the PWA requirements. General wage determinations issued by the Department of Labor’s Wage and Hour Division on www.sam.gov provide the appropriate prevailing wages for PWA requirements. The Final Rule lists Form WH-347 (the Davis-Bacon form for certified payroll) as one example of a record that may demonstrate compliance with PWA requirements.

Notably, however, the Final Rule distinguishes prevailing wage requirements from Davis-Bacon Act requirements – noting that prevailing wage requirements pursuant to the IRA are not a mirror of the Davis-Bacon Act, but instead may be merely in harmony with Davis-Bacon requirements. Treasury and the IRS therefore declined to implement certified weekly payroll, public notice, and other Davis-Bacon Act requirements as part of the PWA requirements.

While the Davis-Bacon Act focuses on the “site of the work” to determine when prevailing wages must be paid, the Final Rule uses a similar concept of “the locality in which a facility is located.” The locality in which a facility is located is the physical place or places where the facility will be placed in service and remain – commonly understood as the project site. It also includes secondary locations where a significant portion of the facility is constructed, altered, or repaired – but excludes secondary locations for fabrication or manufacturing that are not established specifically or dedicated exclusively for a specific period of time to the facility.

Significantly, the Final Rule largely resolves the question of which prevailing wage applies to a facility. It confirms that the prevailing wage in effect at the time the agreement for construction, alteration or repair of the facility is executed is the wage that applies for purposes of the PWA requirements. The same wage general wage determination may still be used if the contractor is given additional time to complete its original commitment or if additional work is incorporated into the agreement that is “merely incidental,” which provides reassurance with respect to usual course of business change orders during construction of a facility. If, however, the agreement is modified to include “additional substantial construction, alteration or repair work not within the scope of the work of the original contract,” or if the agreement is modified to “required work to be performed for an additional time period not originally obligated,” including exercise of an option to extend the terms of an agreement, a new general wage determination will be required.

For wage determinations needed and not covered by a general wage determination, the Final Rule generally follows the NOPR’s outline for submission of supplemental wage determination requests to the Wage and Hour Division. The Final Rule notes that taxpayers, contractors or subcontractors may submit supplemental wage determination requests. Such requests should be submitted no more than 90 days before the expected execution of a construction contract (or at any time following execution), and will remain effective for 180 calendar days after they are issued (or for the duration of the time the supplemental wage determination is incorporated into the contract).

The Final Rule also provides that the Wage and Hour Division will resolve supplemental wage determination requests, or notify the requester that additional time is necessary, within 30 days of submission of a request. If a supplemental wage determination is issued after construction work has started on the facility, it applies retroactively to the date construction started.

Third, with respect to apprenticeship requirements, the Final Rule incorporates many proposed regulations from the NOPR, including the three-pronged approach necessary to comply: taxpayers must ensure the labor hour requirement, the ratio requirement, and the participation requirement are each satisfied.

Many of the ambiguities raised in comments to the NOPR regarding apprenticeship focused on the Good Faith Effort Exception, and the Final Rule addresses several of them. Requests made to registered apprenticeship programs must be made in writing and sent electronically or by registered mail. Initial requests must be made no later than 45 days before the qualified apprentices are requested to start work, and subsequent requests must be made no later than 14 days before the qualified apprentices are requested to start work. The content of each request remains as outlined in the NOPR.

The Final Rule extends the period between requests on which a taxpayer may rely on the Good Faith Effort Exception to a full calendar year. In the event a request to a registered apprenticeship program is either denied or not responded to, a taxpayer will need to ensure an additional request is submitted annually in order to rely on the Good Faith Effort Exemption. There is no limit on the number of requests that may be submitted to a program, and there is no requirement to make subsequent requests to the same program (or to follow up on requests that are not responded to).

If a request to a registered apprenticeship program is partially denied, in order to satisfy the Good Faith Effort Exception requirements, the requesting party must accept the qualified apprentices offered (and may then consider the remaining portion as labor hours performed by qualified apprentices). An employer-sponsored registered apprenticeship program may not be used by such employer to satisfy the Good Faith Effort Exception requirements, unless the employer submits compliant requests to at least one registered apprenticeship program that it does not sponsor.

Finally, the Final Rule outlines in a separate recordkeeping section a list of records that may be sufficient to demonstrate compliance with PWA requirements. It notes that taxpayers may satisfy such recordkeeping requirements by collecting and physically retaining the records; providing them to a third-party vendor; or having each party physically retain relevant records (unredacted copies of which must be made available to the IRS upon request).

It confirms again that taxpayers are entitled to a rebuttable presumption of no intentional disregard if a taxpayer makes the appropriate correction and penalty payments before receiving notice of an examination from the IRS with respect to a claim for the increased credit. While continuing to emphasize that findings of “intentional disregard” of the PWA requirements will be made based on specific facts and circumstances, the Final Rule also provides 15 examples (for prevailing wage compliance) and 13 examples (for apprenticeship compliance) of facts and circumstances that may be considered in such a finding, including whether the failure was a pattern of conduct, whether the taxpayer took reasonable steps to monitor, review and correct compliance efforts, whether the taxpayer incorporated provisions in its agreements requiring compliance with the PWA requirements, and what documentation and records the taxpayer collected to ensure such compliance.

The Final Rule also establishes a 180-day limit for the taxpayer to pay correction and penalty payments following a final determination from the IRS that the taxpayer has failed to satisfy PWA requirements.

Overall, the Final Rule provides helpful clarity to renewable energy developers and contractors enacting and enforcing PWA requirements throughout the industry. However, leaves open industry-specific questions such as what scope of work constitutes “repair” rather than “maintenance,” particularly during operation of a facility. It also fails to address whether on-site commissioning work constitutes “construction, alteration or repair” sufficient to trigger obligations to comply with PWA requirements. These questions will remain subject to assessment based on specific facts and circumstances, and prudent industry developers and contractors will need to carefully consider and document how they approach compliance with PWA requirements consistent with prudent industry practices.

Monica Dozier and Jennifer Trulock are partners at Bradley Arant Boult Cummings LLP and regularly advise clients on labor and employment issues in the renewable energy industry.

From pv magazine Global

Chinese solar module maker CGL Technology presented its latest perovskite solar module technology at the Intersolar tradeshow in Munich, Germany, this week.

“This module has met IEC testing standards that would suggest it would degrade in a pattern that is similar to standard silicon solar modules,” the company’s spokesperson, Martin Wang, told pv magazine, noting that the company expects this perovskite product to be deployed as part of a perovskite-silicon tandem solar module which will begin mass production in late 2025.

Wang also revealed that GCL perovskite modules were used in the 1 MW perovskite solar power project deployed by China Three Gorges in late 2023.

The company said the deployment of their pure perovskite module at the China Three Gorges solar project represented the state-of-field testing stage of the product. The company hopes to deploy multiple 1 MW projects before the end of the year across different geographies with different environmental traits, to test the viability of the perovskite module.

At the booth, GCL showed two perovskite solar modules: one a pure perovskite module, and the other a perovskite silicon tandem solar module. The pure perovskite module has an efficiency of just over 19%, while the tandem module’s efficiency is just over 26%.

Wang explained that the perovskite solar panel had passed TUV Rhineland IEC 61215 and IEC 61739 certification tests, which would suggest that the solar modules would degrade like a standard silicon solar panel. Wang implied that GCL was moving slowly into the market with that statement because the tests are designed to degrade silicon products, and not perovskite products.

GCL has supplied pv magazine with the IEC certification document. Further documentation to better interpret the degradation results has been requested.

The modules came from a 100 MW test line that has been in place since 2021. The majority of the modules from this test line, which totaled 10 to 15 MW in 2023, have been recycled, as the modules progressed toward units they felt were worthy of deployment.

Wang said that GCL believes the degradation of their perovskite silicon tandem module will be better than that of standard silicon modules. Starting at the end of next year, GCL will begin deploying their perovskite silicon tandem solar module.

A key detail on the product that is different from many others in the market is that the tandem aspect of the product is on a module level – not the cell level. What this means to the manufacturer is that “95% of the hard work” will have already been done in the creation of the perovskite module.

Wang also explained that combining two solar panels was a much simpler process than making a tandem solar cell, and that of the hand-crafted perovskite silicon tandem modules, the units work 95% of the time, and that once the manufacturing line is in place this value will reach near 100%.

Wang said that on a cost-per-watt basis – not expected market price – the company expected the perovskite silicon tandem module would cost 50% of a crystalline silicon module that costs $0.15 per W, meaning $0.075 per W. He said the 50% value that was used in marketing on the perovskite silicon module was done when polysilicon was more expensive, and thus modules were more expensive.

When asked by pv magazine about future efficiency gains, Wang said GCL – in this case – is a perovskite company first. “We should realize the full potential of perovskites, and we should adapt silicon to the perovskite – instead of the other way around,” he stated.

By next year, they expect the tandem module to break 27% efficiency – with greater than 30% “guaranteed”. Currently, in the tandem structure, it is the perovskite module that is contributing the majority of the efficiency, as it is generating at 19% – while the silicon is only running at 7% efficiency.

The current silicon base module used is a TOPCon unit, however, GCL believes that heterojunction will be the best long-term solution due to the product’s higher voltage.

From pv magazine 6/24

The United States has set a goal of achieving 100% clean energy by 2035. To do so, a vast amount of land needs to be used for solar energy production. The US National Renewable Energy Lab estimates that if the United States were to meet all of its electricity needs with solar alone, around 10 million acres, or 0.4% of the area of the country, would be needed.

Solar siting can run into local opposition, so public perceptions need to be addressed. That was the subject of “Perceptions of Large-Scale Solar Project Neighbors: Results from a National Survey,” a report conducted by the Energy Markets and Policy (EMP) department at the Berkeley National Laboratory, in collaboration with the University of Michigan and Michigan State University.

The impetus for the study is the tremendous buildout of large-scale solar (LSS) plants (greater than 1 MW) across the United States. According to the US Solar Photovoltaic Database, as of November 2023 there were 3,676 solar projects with capacities of more than 1 MW, for a total generation capacity of 54.9 GW. As of 2022, there were more than 10 million US homes within 4.8 km of LSS plants.

Understanding the perceptions and attitudes of people who live near these installations can help with future deployment, according to Joseph Rand, lead author of the study and an energy policy researcher in the EMP department at Lawrence Berkeley National Laboratory.

As no study had previously been done asking LSS site neighbors for input, the Berkeley group teamed up with the University of Michigan and Michigan State researchers to conduct a survey of residents who live within three miles of 380 unique LSS projects ranging in size from 1 MW to 252 MW in 39 states.

Rand noted that it is early in the analysis of survey results but the key takeaways at this point are that residents had more negative reactions to installations greater than 100 MW in scale. He said the planning process also plays an important role in perception, because if residents “thought the planning process went well, they were more positive overall.”

Part of the planning process is communication about a project. Rand said the biggest surprise in the survey results was that less than one-fifth of respondents actually knew about projects before construction.

A team from the University of Michigan sent out the questionnaire along with a map showing solar power plants in close proximity to survey recipients.

The survey asked several questions aimed at determining how LSS development impacted local tax revenue, supported local workers, or contributed to the local economy overall. On employment, only 18% of respondents thought an LSS project impacted local job opportunities, with 13% of respondents saying it increased employment opportunities and 5% that it decreased them. Almost half the respondents said there would be “no effect” on employment opportunities. Most respondents did not notice any short- or long-term economic impact, although the researchers found that these perceptions were tied to attitudes about projects overall. Likewise, most respondents did not believe that projects affected local inequities.

Researchers were interested in how LSS site neighbors can play a larger role in local development and the responses showed developers can do a better job of informing the public about plans so they can play a role in LSS projects. Questions asked whether respondents were aware of projects, whether developers offered opportunities for neighbors to participate in public meetings during the planning process, and to what extent they had participated.

While respondents did not prefer increased state-level decision-making in future LSS siting decisions, they did want more opportunities to participate in decision-making and liked the idea of having third-party advocates inform neighbors of the planning process and to intervene on their behalf.

In asking how LSS site developers might locate projects that were considerate of local land-use plans, as well as community needs and values, 42% of respondents said they would support additional LSS sites in their community – compared to 18% that would oppose it – but they preferred that projects be sited on disturbed locations such as landfills and former industrial sites, rather than in forests or on productive farmland.

Savvy developers and local officials can gain much from the in-depth report, Rand said. While attitudes in general were found to be more positive than negative, the survey found a significant amount of negativity around very large projects. This is a signal that, if building very large solar sites, “developers really want to listen to the public and do a thorough planning process so people are aware of the project,” Rand said. “If I were a developer, to help the public understand a project, it’s important that that information is provided from trusted sources.” Such sources are not energy developers or state policymakers, but university faculty and staff, or non-profit organizations.

From pv magazine Global

The Global Polysilicon Marker (GPM), the OPIS benchmark for polysilicon outside China, was assessed at $22.567/kg this week, unchanged from the previous week on the back of buy-sell indications heard. The price has held steady for four consecutive weeks.

According to a source knowledgeable about the polysilicon market outside of China, the trading status of global polysilicon in the spot markets is currently largely stagnant, with buyers awaiting the preliminary ruling from the U.S. anti-dumping and countervailing duties investigations expected in July.

A major global polysilicon buyer reported receiving spot prices from certain sellers lower than long-term agreement prices for the same specifications. However, due to uncertainty in US trade policy, they have refrained from placing an order.

This information was corroborated by a global polysilicon supplier, who expressed concern: “We are worried about inventory accumulation.”

Nevertheless, there are still optimistic voices lingering in the market, with sources reporting ongoing positive sales experiences. One of the sources explained that the solar supply chain features three distinct supply-demand relationships: between polysilicon and wafers, wafers and cells, and cells and modules.

“It’s argued that applying the current pessimism from the module market to the global polysilicon market is unjustified,” the source added. “Only the relationship between polysilicon and wafers directly influences the pricing of global polysilicon, which has been proven to be stable without notable fluctuations.”

China Mono Grade, OPIS’ assessment for polysilicon prices in the country, remained steady at CNY33 ($4.54)/kg this week, marking the fourth consecutive week of stability.

The market participants generally believe that current polysilicon prices do not need further reduction, as it would not significantly stimulate sales. Wafer companies are constrained by their operating rates and cash flow, limiting their ability to accelerate polysilicon procurement. “We are currently facing a loss of approximately 0.20 yuan for every piece of wafer produced,” a major wafer producer disclosed.

Multiple sources have confirmed that while nearly all Chinese polysilicon manufacturers are undergoing equipment maintenance, production cuts, or shutdowns, one major manufacturer is operating at full capacity with a 100% operating rate.

As a result, this company is incurring a monthly loss of CNY600-700 million in the polysilicon manufacturing segment, a source commented, noting that due to the factory’s large production capacity, operating at full capacity will keep overall polysilicon inventory levels high, casting uncertainty over the prospects for polysilicon prices.

Sources indicate that in addition to operating at full capacity, the company’s new production capacity is also ramping up as scheduled. This strategy underscores the company’s robust cash flow and its intent to leverage scaled capacity and cost advantages to squeeze the survival space of smaller companies in the ongoing price war.

According to an industry watcher, the current situation of selling polysilicon at a significant cash loss is unsustainable. By the end of the year, prices are expected to stabilize slightly above the average cash cost in the market, the source noted, who further anticipates that at that point, some excess production capacity, particularly high-cost or outdated facilities, will likely be phased out effectively.

OPIS, a Dow Jones company, provides energy prices, news, data, and analysis on gasoline, diesel, jet fuel, LPG/NGL, coal, metals, and chemicals, as well as renewable fuels and environmental commodities. It acquired pricing data assets from Singapore Solar Exchange in 2022 and now publishes the OPIS APAC Solar Weekly Report.

The New York State Public Service Commission approved a new framework for New York to achieve 6 GW of energy storage by 2030, representing at least 20% of the peak electricity load of New York State.

The original Energy Storage Order was developed in 2018 and had a target of 3 GW of energy storage. However, New York set ambitious clean energy goals through the Climate Leadership and Community Protection Act, including generating 70% of the state’s electricity from renewable sources by 2030 and 100% zero emission electricity by 2040. The new order doubles the energy storage goals set in 2018, increasing the target to 6 GW by 2030.

The funding authorizes $814.6 million in total energy storage funding, which breaks down to $675 million for 1.5 GW of community and C&I energy storage incentives, $100 million for 200 MW of residential incentives, and $39.6 million for program administration.

“Expanding energy storage technology is a key component to building New York’s clean energy future and reaching our climate goals,” said Governor Hochul. “This new framework provides New York with the resources it needs to speed up our transition to a green economy, while ensuring the reliability and resilience of our grid.”

According to New York State Energy Research and Development Authority (NYSERDA), these future procurements, combined with the 1.3 GW of existing energy storage being procured or already under contract and getting closer to commercial operation, will allow New York to achieve its 6 GW goal by 2030. NYSERDA reports that as of April 1, 2024, New York has awarded about $200 million to support approximately 396 MW of operating energy storage in the state.

“Governor Hochul has long been a staunch supporter of energy storage development in New York State, and with her steadfast support, we have been able to develop this roadmap to guide New York away from fossil-burning power plants to a clean energy economy,” said Rory M. Christian, chair of the Public Service Commission.

The Roadmap includes:

• 3,000 MW of new bulk storage, enough to power approximately one million homes for up to four hours, to be procured through a new competitive Index Storage Credit mechanism;
• Use of at least 35% of program funding to support projects that deliver benefits to Disadvantaged Communities (DACs) and that target fossil fuel peaker plant emissions reductions, with program carve-outs for projects sited in the downstate region, given its high concentration of DACs and peaker plants;
• Requiring electric utilities to study the potential of high-value energy storage projects toward providing cost-effective transmission and distribution services not currently available through existing markets;
• Continued prioritization by existing programs on investing in R&D related to reliable long-duration energy storage technologies; and
• Requiring payment of prevailing wage for energy storage projects with a capacity of 1 MW and above.
• Fire safety requirements must be in NYSERDA Implementation Plans, reflecting recommendations from the Fire Safety Working Group.

“By setting clear and ambitious targets for energy storage deployment and creating robust incentive structures for both retail and residential projects, this order lays the foundation for a cleaner, more reliable energy grid. NYSEIA applauds the dedication and vision of these agencies, and we look forward to continuing our collaboration to achieve these critical goals for the benefit of all New Yorkers” New York Solar Energy Industries Association (NYSEIA) said.

The roadmap will support a buildout of storage deployments estimated to reduce projected future statewide electric system costs by nearly $2 billion, according to NYSERDA, in addition to further benefits in the form of improved public health because of reduced exposure to harmful fossil fuel pollutants.

“With more renewable generation than any other state on the east coast, deep duration storage is only going to become more critical to keeping the lights on as New York continues to work towards its decarbonization goals,” said Jordan Cole, chief commercial officer of Hydrostor. “New York has recognized that 8+ hour storage is needed to move the energy transition forward while maintaining the reliability of the grid, and we’re confident that other states will follow. We look forward to working with NYSERDA on its implementation plan.”

Next steps to be taken include the development of implementation plans by NYSERDA, which will include stakeholder input. The commission will then review and approve the plans before the incentives are made available.

Aiko presents ABC solar module with world record efficiency of 25.2% at Intersolar The Chinese back contact module maker said its new products rely on the company’s all-back-contact (ABC) cell technology and feature a temperature coefficient of -0.26% per C.

People on the move: Amp Energy, Deriva Energy, Atwell LLC, and more Job moves in solar, storage, cleantech, utilities and energy transition finance.

Arizona’s largest energy storage project closes $513 million in financing The 1,200 MWh Papago Storage project will dispatch enough power to serve 244,000 homes for four hours a day with the e-Storage SolBank high-cycle lithium-ferro-phosphate battery energy storage solution. 

Scientists develop silver-free PEDOT:PSS adhesive for shingled solar cells Researchers from the University of California, San Diego (UCSD) have developed a new silver-free adhesive for shingled solar cells. The novel adhesive is based the PEDOT:PSS polymer and can reportedly reduce silver consumption to approximately 6.3 mg/W.

Longi launches ultra-black HPBC solar modules for residential applications The Chinese manufacturer said its new Hi-MO X6 Artist series has an efficiency of up to 22.3% and a power output ranging from 420 W to 430 W. The smaller version is currently priced at CNY 298 ($41.7)/m2 and the largest model is sold at CNY 268/m2.

Nextracker acquires solar foundation specialist Ojjo for $119 million Ojjo makes a unique truss system that reportedly uses half the steel of a conventional foundation and a design that minimizes grading requirements.