Major residential solar installer SunPower has closed its business after standing as one of the oldest and largest distributed solar companies in the United States. Solar panel manufacturer Maxeon announced it will provide warranty support for customers with SunPower-branded modules. 

The companies became two seperate entities when they separated in August 2020, as Maxeon spun off as an independent company focused on manufacturing. Maxeon previously had a supply agreement to provide solar panels to SunPower, but that agreement was terminated in 2023. Since Q1 2024, Maxeon has not been shipping any product to SunPower. 

Support will be issued as follows, according to a note from Maxeon: 

“For support issues on your SunPower solar system, please contact your solar installer. Maxeon will work with your installer to support any applicable warranty coverage. Warranty coverage will be outlined in a new Maxeon warranty document, which will be available soon on Maxeon’s website,” said the company. 

Maxeon products are typically tied to a 40-year warranty, considerably longer than the 25-year industry standard. 

High operating costs pose a substantial barrier to electrification in high-cost regions. Whole house time-of-use rates can lower operating costs but usually not enough to accelerate adoption of heat pumps and EVs. While rebates and income tax credits provide substantial financial incentives that lower the capital and installation cost of as heat pumps for HVAC and electric vehicles (EVs), they don’t lower their operating costs.

We need a new rate design paradigm that satisfies three conditions: Makes electrification affordable, recovers the utility’s revenue requirement, and does not unleash a public outcry

Under the existing paradigm, rate design should not be technology-specific. Under the new paradigm, marginal cost pricing would only be applied at the margin for incremental consumption associated with the installation of heat pumps and EV chargers.

This approach is not without precedent. Today, a few utilities allow EVs to be charged a rate that is specific to that vehicle if they install a separate meter. Other utilities are examining the use of telematics to bill EV customers for charging their vehicles at home.

As for heat pumps, Artificial Intelligence (AI) may be able to infer the incremental load associated with electrification to which marginal cost pricing would be applied.

A case study

Consider the case of Pacific Gas & Electric Company, which serves more than 5 million customers in northern California. The average residential rate currently stands at 42 cents/kWh. Using the E-1 tiered rate as a point of reference, the price of electricity has doubled over the past seven years, far exceeding the rate of inflation. In the seven years prior to 2017, it had only grown by 23%. As a point of reference, in 2008 the rate stood at 16.4 cents/kWh. More increases are expected to occur at year end, with the average rate possibly reaching 50 cents/kWh.

One of the popular rates being used by its EV customers is EV2-A. The rate features three pricing periods. During the summer, the off-peak rate is 31 cents/kWh. If EV load is priced at the marginal cost of electricity, the price may drop to 10 cents/kWh.

A typical household whose EV load is 3,000 kWh a year would see their annual EV driving costs drop substantially from $930 to $300. This would substantially enhance the appeal of EVs to drivers who are in the market for a new car, and probably accelerate the EV adoption rate.

In the areas that lie east or south of San Francisco, or in the Central Valley, summers are hot and winters are cold. A heat pump for heating, ventilating and air conditioning (HVAC) may consume 3,500 kWh a year. If the year-round peak period price averages 55 cents/kWh, the mid-peak averages 49 cents/kWh and the off-peak price averages 31 cents/kWh, then a weighted average price of 45 cents/kWh may be used to get a ballpark estimate of the annual operating cost of a heat pump.

With the existing rate, that would amount to roughly $1,575. If a marginal price of 15 cents/kWh is used, the cost would drop to $525, making it a substantially more attractive investment for customers, and probably accelerating the adoption rate. In both cases, operating costs fall by two-thirds, as brought out in the figure below.

In some areas, electrification might run into distribution capacity constraints, requiring capacity expansion. In such cases, estimates of marginal capacity costs would be added to marginal energy costs. In addition, electrification-focused marginal cost pricing should feature time variation in energy rates to avoid creating new peaks and to facilitate load flexibility.

Society as a whole will benefit through the reduction of carbon emissions that will accompany electrification. Climate change will be mitigated. Customers who electrify will see lower bills compared to what they would be paying with gas furnaces and ICE vehicles. There will be no losers. No one will see higher bills.

Dr. Faruqui is an Economist-at-Large who has been working on energy issues since the summer of 1976, when he interned at the California Energy Commission. From 1978 to June 1979, he was a full-time analyst at the CEC. Subsequently, he worked at the Electric Power Research Institute for 11 years and then at several consulting firms, most notably Barakat & Chamblerlin, Charles River Associates, and The Brattle Group.

Schools in the United States from kindergarten through high school are adopting solar energy in significant numbers. A report from Generation180 found that one in nine students in K-12 have solar at their school.

Energy is second only to teacher salaries when it comes to cost, according to NREL, and U.S. schools spend more than $6 billion a year on the line item. Solar presents an opportunity for schools to alleviate budget pressure, often at little or no upfront cost, freeing up funds for more educational benefits.

Schools often sign a power purchase agreement (PPA) when going solar, allowing the school to buy the electricity produced by the solar installation for 10 to 25 years at a discounted rate, serving up cost savings from day one. Generation180 said about 80% of schools go for the PPA route, while about 12% opt for direct ownership via cash, loan, or bond, and 8% own the system through grants, government funds, or private donations.

Generation180 has tracked school solar data since 2014. Over the ten year span of the report, solar capacity at schools has more than quadrupled from 422 MW to 1,814 MW. Nearly 9,000 schools now have solar, and the average system size has grown about 50% from 134 kW to 202 kW.

“During the past ten years, the falling installation price made going solar an affordable option for more schools. Between 2014 and 2024, the cost to install solar dropped by 40%,” said the report from Generation180. “There has never been a better time for schools to flip the switch to clean energy.”

California has the most solar schools in the nation with 2,815, this is followed by New Jersey (696), Illinois (568), Arizona (411), and Connecticut (336). In terms of percent of schools that have adopted solar, the rooftop solar-friendly state of Hawaii leads the way with 30% of schools, followed by Connecticut (27%) and Washington D.C. (24%).

As for energy storage, which is increasingly being attached to solar projects from the residential to the utility-scale, schools have yet to adopt this technology. As of January 2024, approximately 40 schools across six states had installed battery storage with a cumulative power capacity of 7.7 MW, according to Generation180.

“Excess energy produced by the solar panels can be stored for later use,” said Generation180 on the benefits of storage. “The stored energy can be discharged to the grid when electricity rates are peaking, resulting in utility bill savings. During grid outages, energy storage can be used to power the building and keep the school operating for students or as a community shelter during natural disasters.”

Generation180 said there is much to look forward to with the buildout of solar on schools. Projects are being built via federal funding allocated by the Bipartisan Infrastructure Law, including over $3.1 billion in funding already awarded to K-12 public schools through the EPA Clean School Bus Program and Department of Energy’s Renew America’s Schools Program.

Furthermore, the first clean energy tax credit payments, enabled by Elective Pay, or direct pay, in the Inflation Reduction Act will be issued to schools in 2024. Under IRA, schools can qualify for up to a 50% tax credit when combining the base credit 30% with a domestic content bonus of 10% and an Energy Community bonus of 10%.

Montreal-headquartered EVLO Energy Storage, a subsidiary of Hydro-Québec, announced the launch of a new energy storage product called EVLO Synergy.

The product is a 20 foot containerized lithium ferro-phosphate (LFP) battery energy storage system that carries 5 MWh of power and flexibly operates in two or four hour durations.

EVLO said the storage system is fully tested and integrated, minimizing onsite work when installing the battery. The product meets NFPA 69 safety standards and is UL 9540 certified.

The company said the Synergy battery can run for up to 9,125 cycles over 25 years without the need for battery replacements.

The battery emphasizes the company’s commitment to “advanced, safe, and cost-effective energy solutions that support our customers’ requirements for clean energy projects,” said Sonia St-Arnaud president and chief executive officer, EVLO.

The enclosure dimensions are 6.06 m x 2.44 m x 2.90 m (20 ft by 8 ft by 9.5 ft). Operating temperatures range from -30°C to 55 °C (-22°F to 131°F).

The storage system’s software is cloud-based and NERC CIP-ready. It enables onsite and remote supervision and control, and has utility-grade SCADA security for industrial operations.

Globally, energy storage capacity is projected to exceed 1 terawatt-hour by 2030 according to BloombergNEF. Energy storage provides electric grid services like frequency regulation, peak shaving, capacity services, renewable energy integration, and a range of other cost-effective grid stabilizing services.

EVLO will unveil EVLO SYNERGY at the renewable industry conference RE+ in Anaheim, California. Visit Booth #N89019 on September 10, 2024, at 4 p.m. for an exclusive presentation.

Arevon Energy announced it has begun construction on a 192 MW solar project in Pike County, Indiana. The developer, owner and operator held a groundbreaking event August 21.

Ratts 1 Solar project is located in the city of Petersburg, adding enough power for the equivalent demand of about 24,000 homes once completed. Along with the 73 MW Heirloom Solar project also developed by Arevon, the two projects represent nearly $400 million in investment in Pike County.

“This project is an important part of our overall power supply portfolio. It is an Indiana resource and will aid IMPA in achieving our mission of bringing a low cost, reliable, and environmentally responsible power supply to our 61 member communities,” said Kyle Brouillette, senior vice president, market operations and planning at Indiana Municipal Power Agency.

Construction of the projects is expected to employ 200 full-time workers. Primoris Renewable Energy is operating as the projects’ construction contractor.

“The conversion of some of our fields from growing traditional crops to also housing solar panels is an exciting opportunity for our community,” said Dr. Suzanne Blake, Ratts 1 Solar Project participating landowner.

In addition to Ratts 1 Solar and Heirloom Solar, Arevon issued announcements on a $352 million financing package to build the 228 MWdc Posey Solar Project in Indiana and announced the start of construction in May. The company said it will announce the start of construction of an additional utility-scale project in Indiana in the coming weeks

Storage provider National Storage Affiliates Trust (NSA) announced it has entered an agreement with Solar Landscape to develop over 100 MW of rooftop solar across its locations in 42 states and Puerto Rico.

The rooftop solar portfolio is among the largest of its kind in the United States, representing a commitment to covering over 8.5 million square feet of rooftops with solar panels. The projects will be installed across roughly 1,000 NSA properties.

Development of the first sites has already commenced. The projects will require no capital expenditure from NSA. Solar Landscape will develop, own, and operate the assets.

Under the agreement, the solar installations on NSA rooftops will power nearby homes and businesses via a community solar model. In addition to delivering environmental benefits and lowering energy costs, the projects will create a more efficient electric grid by generating clean energy close to where it is used.

(Read: “Major U.S. corporations embracing community solar”)

“We look forward to working with NSA to install community solar projects on their self-storage facilities,” said Solar Landscape chief executive officer and co-founder Shaun Keegan. “Community solar is a win-win-win: it reduces the carbon footprint for communities, offers clean energy at a discount for residents and creates revenue for property owners.”

Solar Landscape introduces people in historically disadvantaged communities to careers in solar. Its nationally-recognized STEP-UP (Solar Training and Education Partnerships for Underserved Populations) program partners with dozens of organizations across the country and has trained more than 2,500 individuals. Last month in Chicago, Solar Landscape and the Hispanic American Construction Industry Association (HACIA) provided hands-on training to community members, building on a program that launched in 2023.

A state entity, the California Public Advocates Office (PAO), released a report suggesting that residents who have invested in rooftop solar should be force-shifted onto a regulatory scheme that would greatly diminish the value of their investments. 

The PAO released a fact sheet claiming that rooftop solar net metering will create an $8.6 billion cost for non-solar customers in the state, and that this number is increasing. As a result, it has advised that net energy metering (NEM) 1.0 and 2.0 customers are forced to shift to the far less advantageous NEM 3.0 rate structure.

The issue at hand is justified based on the “cost shift” problem, a claim backed by utilities that electric bill payers that do not have rooftop solar are subsidizing their solar-installed neighbors. By paying solar customers a retail rate for electricity exported to the grid from a rooftop solar array, utilities say they are incurring a cost that must be paid in the form of raised electric rates.

The California Solar and Storage Association (CALSSA) released a factsheet in response to PAO, debunking PAO’s assumptions about the cost shift. Specifically, it rejects that self-generation of electricity poses a cost to utilities, rejects the assumption that grid infrastructure costs are fixed, and challenges the foundation of the Avoided Cost Calculator, which is used to set the rate for solar exports. More details can be found here.

“For years, the State of California has encouraged people to invest in rooftop solar for the benefit of all. As a result, two million consumers have invested $40 billion to collectively build 12 gas power plants-worth of clean energy. If California goes back on its word, it would not only anger millions of people, it would undermine the solar market going forward as well,” said CALSSA.

The PAO is an agency designed to be a voice for California residents, interacting with the Public Utilities Commission (CPUC) on energy related regulatory issues. It has historically repeatedly released guidance that dovetails with the demands of the state’s three multi-billion-dollar private electric utilities. 

“This cost burden – commonly referred to as a cost shift – to non-rooftop solar customers of Pacific Gas and Electric, Southern California Edison, and San Diego Gas & Electric has risen from $3.4 billion annually in 2021 to $8.5 billion annually by the end of 2024, and it will continue to grow in coming years,” said PAO.

This was the central argument that led to the passage of NEM 3.0, a regulatory structure which transitioned the state from paying lucrative retail rates for solar grid exports to “avoided cost” rates that are roughly 80% lower. The change led to a nosedive in installations in the state, dropping it out of the number one spot for installations for the first time in over a decade.

California has since suffered numerous solar installer bankruptcies and lost tens of thousands of jobs. Solar advocates have argued that while a full retail rate could not be paid forever, the move to NEM 3.0 was too steep of a cut. It’s an issue so contentious that ongoing litigation has brought the issue of NEM 3.0 to California Supreme Court.

For solar owners, PAO suggested the shift from NEM 1.0 and 2.0 to 3.0, also known as net billing tariff (NBT), would occur upon the sale of a home, or after 10 years of interconnection. Most homeowners signed a net metering agreement along with their 25 year loan or lease with the expectation that their agreement would span the life of the solar array. However, net metering agreements do not have any legally binding requirement to grandfather in existing customers for their system’s life.

The PAO also suggested that NEM 2.0 customers have their compensation rates frozen to the time in which they signed the agreement. Rather than being paid a retail rate that increases with the ever-rising electric utility rates, it would remain fixed, cutting down on the benefit of solar.

Silver linings?

However, NEM 3.0, while a shot to the hamstring for the solar industry, has come with some benefits. More than half of solar installations are now opting to include battery energy storage, up from 20% or less in 2023. This may provide critical for California’s clean energy transition, as the intermittent cycles of generation of solar do not match up directly with when power is being used.

This mismatch can be best described with a chart known as the “duck curve,” which shows the daily imbalance the California grid struggles with. Battery energy storage allows this duck curve to be smoothed out, delivering power when demand reaches a high point. This helps grid managers avoid building out inefficient natural gas “peaker” plants to serve those high-demand hours.

Vincent Ambrose, chief commercial officer, FranklinWH told pv magazine USA about the many ways batteries can help solar evolve and continue to serve California residents’ power demands.

“You can think of PV like a knife, it cuts one way, does one thing, and does it efficiently. It produces electricity,” said Ambrose. “When you take a look at an energy management system with a battery, now you’ve got a Swiss Army Knife. It serves all kinds of functions, whole-home backup, peak shaving, load management, even grid-interactive services.”

While batteries offer customers at home a lot more flexibility, those that were sold a solar array with no battery during NEM 1.0 and 2.0 may find themselves in a financially precarious position on their investment should the PAO’s suggestion become reality.

Large corporation Nestlé announced it has invested in a 326 MW solar project owned and developed by Enel North America.

The project, called Stampede, is planned to be installed on 2,600 acres in Hopkins County, Texas. The solar facility also includes plans for an 86 MW battery energy storage system.

Nestlé will purchase 100% of the renewable electricity attributes generated by the project’s energy production, estimated to be an average of over 522,000 MWh per year for 15 years. The annual carbon emission reduction is expected to be an estimated 279,000 metric tons of CO2, equivalent to the emissions of removing about 66,000 cars from the road per year.

“Our investment in Stampede brings us within striking distance of meeting our ambition to source 100% renewable electricity at all our manufacturing sites by 2025,” said Kate Short, chief procurement officer, Nestlé North America. “Building on our previous solar investments, Stampede helps further reduce carbon emissions in our operations and expands the availability of renewable energy—the project adds enough solar electricity to the U.S. grid to power the equivalent of approximately 49,000 households each year.”

The 326 MW Stampede project is the company’s third large scale solar project investment in the U.S., adding to 2023 investment in solar project Ganado and its 2020 investment in solar project Taygete I.

TMEIC Corporation Americas announced it will relocate its headquarters to Houston, Texas in March 2025. The headquarters move will coincide with the establishment of a new 144,000 square foot manufacturing facility in Brookshire, Texas.

TMEIC will manufacture utility-scale solar inverters at the facility. The company said the site is large enough to scale up to an annual production capacity of 9 GW of inverters and will scale based on demand.

The company has over 50 GW of its product installed and operational worldwide, with 28 GW installed in North America alone.

TMEIC is moving its headquarters from Roanoke, Virginia to Texas for the site expansion. TMEIC will maintain its office in Roanoke, Virginia, remaining devoted to designing, developing, and engineering advanced automation systems, large AC motors, and variable frequency drive systems for various industrial sectors worldwide.

The new Texas facility expansion is expected to create up to 300 local full-time jobs.

The Brookshire, Texas facility is scheduled to commence operations in October 2024. The facility will be situated near TMEIC’s existing uninterruptible power supply and medium voltage drive manufacturing plant in Katy, Texas. 

“This strategic expansion underscores TMEIC’s dedication to the renewable energy industry, advancing clean energy technology, maintaining strong client relationships, and competing on a global basis while proudly manufacturing in the United States,” said Manmeet S. Bhatia, president and chief executive officer, TMEIC Corporation Americas.

TMEIC manufactures centralized PV inverters ranging from 600 V to 1500 V.

TMEIC joins a small but growing number of solar inverter makers who are manufacturing in the U.S., thus filling what has long been a void in the U.S. solar supply chain.

The Global Polysilicon Marker (GPM), the OPIS benchmark for polysilicon outside China, was assessed at $22.567/kg this week. This is unchanged from the previous week, as the fundamentals of this market segment remain largely stable for now.

Wafer plants in Southeast Asia have reportedly ramped up their operations recently, with the purpose to redirect these wafers to countries in the region outside the four countries currently under U.S. investigation, where they are processed into cells and modules intended for sale in the U.S. market.

This trend hasn’t led to changes in global polysilicon transaction prices. A Southeast Asian wafer producer mentioned preferring to buy polysilicon from traceable regions in China to reduce costs. Additionally, current global polysilicon inventories, built up from a sluggish spot market, are adequate to meet the slight increase in demand resulting from higher wafer production rates in Southeast Asia.

The fire triggered by a pipe explosion at a global polysilicon factory last week has drawn significant attention in the market. However, market participants agree that the incident will have a limited impact on the factory’s production capacity and is unlikely to affect global polysilicon prices.

This is partly because the manufacturer holds excess inventory after a customer postponed some regular monthly orders under a long-term purchase agreement, according to a market source. Additionally, with ongoing uncertainty around U.S. investigations into imported cells and modules from four Southeast Asian countries, global polysilicon demand remains subdued, further minimizing the potential impact on prices.

China Mono Grade, OPIS’ assessment for mono-grade polysilicon prices, held steady at CNY 33 ($4.62)/kg this week, marking twelve consecutive weeks of stability. Meanwhile, China Mono Premium, OPIS’ price assessment for mono-grade polysilicon used in N-type ingot pulling, rose by 1.79% from last week, reaching CNY 39.7 ($5.56)/kg.

The increase in prices of polysilicon used in N-type ingot pulling is attributed partly to a few wafer factories restocking their polysilicon inventory after depletion, and partly to futures and spot traders accumulating polysilicon in preparation of its potential listing as a futures commodity.

Major polysilicon giants, with their cost advantages and control over much of the market’s inventory, are increasingly demonstrating strong pricing power in the Chinese market. As smaller companies produce at limited operating rates, their regular customers are now turning to these major factories for spot purchases, further strengthening the giants’ influence on prices.

With the dry season approaching in two months in Sichuan and Yunnan – regions reliant on hydroelectric power and home to many polysilicon factories – rising electricity costs are expected to push up production costs. This will likely make it even harder for smaller, shuttered polysilicon enterprises to resume operations, thereby amplifying the pricing power of the major producers.

A market observer suggested that polysilicon giants may continue to raise prices, potentially reaching around CNY 50 ($7.01)/kg, slightly above their production costs. However, this level remains well below the cost threshold for smaller producers and is unlikely to spur the reopening of closed small factories.

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.

Canadian Solar (Nasdaq: CSIQ), a global provider of solar modules, energy storage, and other clean energy components and solutions, announced its Q2 2024 earnings

The company posted $1.64 billion in revenues, roughly coming in line with Wall Street expectations. However, revenues are down from $2.36 billion in Q2 2023, and the company’s share price declin.ed about 15% in the trading session following the earnings report.

Canadian Solar attributed the decline in revenues to sharply falling global solar module prices.

Total module shipments recognized as revenues in the second quarter of 2024 were 8.2 GW, up 30% quarter-over-quarter and remained consistent year-over-year. Of the total, 135 MW were shipped to the company’s own utility-scale solar power projects.

“Today, we have reached an optimal scale—large enough to maintain a highly competitive cost structure yet lean enough to adapt swiftly to changes in industry dynamics,” said Dr. Shawn Qu, chairman and chief executive officer, Canadian Solar.

Shares fell as Canadian Solar forecast third quarter revenues of $1.6 billion to $1.8 billion, significantly lower than Wall Street expectations of $2.22 billion. The company now guides $6.5 billion to $7.5 billion for full year revenues, falling short of analyst estimates of $7.66 billion.

The company recorded 17.2% gross margin, in line with guidance of 16% to 18%. Its e-STORAGE order backlog grew to $2.6 billion, backed by a record 66 GWh of pipeline, as of June 30, 2024.

Its solar project development arm Recurrent Energy expanded its total development pipeline to 27 GW of solar and 63 GWh of battery energy storage, as of June 30, 2024. The company also achieved initial closing of BlackRock’s investment in Recurrent Energy, representing the majority of the planned $500 million capital infusion. During the quarter, the company also announced a $200 million private placement of secured convertible notes with PAG.

“In our module business, we continue to apply a disciplined approach to operations, from strategic capacity investments to stringent order management. At the same time, we are positioning ourselves for sustainable medium- and long-term growth through our energy storage business, e-STORAGE, and global project development platform, Recurrent Energy,” said Qu.

The company said Recurrent Energy will continue to increase leverage in the near-term to support its transition to a partial independent power producer (IPP) model. As of June 30, 2024, Recurrent Energy’s total solar project development pipeline was 27.4 GW, including 1.7 GW under construction, 4.8 GW of backlog, and 20.9 GW of projects in advanced and early-stage pipelines.

“While we continue to navigate challenging market conditions, our focus remains on sustainable, profitable growth. We are beginning to see signs of market rationalization, as module pricing and input costs reach record lows. In line with our commitment to strategic future planning, we are adjusting certain capacity investments to ensure a resilient financial profile. We anticipate stabilization in the second half of the year,” said Qu.

General Motors (GM) announced it has entered a 15-year power purchase agreement (PPA), signing on to purchase electricity generated by a 180 MW solar project.

The agreement with solar developer NorthStar Clean Energy will enable GM to power three of its assembly plants with clean energy. The project in Newport, Arkansas, will support the electricity needs of GM’s Lansing Delta Township Assembly and Lansing Grand River Assembly in Michigan, and the Wentzville Assembly site in Missouri.

The Newport Solar project is expected to generate enough electricity to power over 30,000 homes per year.

“By expanding our renewable electricity portfolio, we are taking a major step forward in reducing our carbon footprint and advancing our broader sustainability goals,” said Rob Threlkeld, GM director of global energy strategy. “This facility not only supports our renewable electricity strategy, but also demonstrates our dedication to a sustainable future for all.”

The project won’t directly power GM plants, but rather will provide GM with renewable energy certificates (REC) that help the company achieve its state environmental, social, and governance goals. Such REC contracts are often facilitated by Southeast U.S. states, where the grid has some of the worst carbon pollution in the nation.

While RECs help attract investment and development in these regions, critics have warned that they are misleading in the purported environmental benefits. Projects often sell electricity and RECs as two separate assets.

GM now has sourcing agreements with 17 renewable energy projects across 11 states. BloombergNEF lists GM as the automotive industry’s largest buyer of renewable power capacity.

D.R. Horton, among the largest new home builders in the United States, announced it has selected Streetleaf as a national vendor. 

In the agreement, Streetleaf will provide its solar-powered streetlamps to D.R. Horton for its new construction communities. 

Streetleaf’s latest streetlamp includes a 21% efficiency solar panel, 220W high-efficiency LED lights, and an NiMH battery. The resilient structure can withstand temperatures up to 158 degrees F and winds of 160 mph. It an be installed at heights 15 to 25 feet and is available in black or white.

“Any housing project being developed without solar-powered streetlights is a missed opportunity for the future of that community,” stated Liam Ryan, chief executive officer of Streetleaf. “The demand for sustainable living solutions is growing exponentially and our streetlights are attracting the attention of potential homebuyers.” 

D.R. Horton already installs smart home technology in every home it builds. Now the company is incorporating smart neighborhood solutions, including solar-powered streetlights from Streetleaf. 

“Sustainable infrastructure is highly attractive to homeowners, and the added peace of mind that comes with knowing the lights are designed to remain operational even during many extreme weather events like hurricanes is equally important,” said Brad Conlon, senior vice president, business development, D.R. Horton. 

Over 7,300 Streetleaf streetlights have already been installed in more than 100 projects across the U.S. This has led to an estimated 2.6 million pounds of CO2 savings compared to traditional streetlights, said the company. 

Middle-market infrastructure investment firm Nova Infrastructure announced it has completed its purchase of UGE International, a solar and energy storage developer and operator.

The acquisition includes Nova purchasing approximately 70% of UGE’s shares. The company is publicly traded on the TSX Venture Exchange.

UGE is a solar operator and developer of rooftop and ground mount commercial, industrial and community solar energy solutions. Founded in 2010, UGE develops, builds, finances, owns and operates solar and battery storage projects in New York, New Jersey, Maine, California, Pennsylvania, Oregon, Texas, Illinois, Maryland, Virginia and Massachusetts.

The company has delivered over 500 MW of projects and currently has a portfolio of more than 12 operating and 81 advanced backlog projects in 11 states. UGE is a community solar and battery storage platform with a vertically integrated business model and a diversified project portfolio.

“Nova committed acquisition capital as well as growth capital to support the expansion of the UGE platform and installed MW,” shared Allison Kingsley, co-founder and partner at Nova.

NOVA was advised in this transaction by Blank Rome LLP and Bennett Jones LLP, and UGE was advised by Mintz LLP and CP LLP.

Enteligent, a startup offering solar-powered DC-to-DC chargers for electric vehicles, announced it has raised $6 million in capital from investors to scale commercialization of its products.

The recent funds bring Enteligent’s capital raise to $19 million since 2021. The funding round was led by Taronga Ventures, a global technology investor in real estate and infrastructure.

Funds will primarily be used to scale commercialization of the company’s DC-based solar optimization solutions. This includes the company’s signature technology, the TLCEV DC-to-DC bidirectional electric vehicle charger. Enteligent said its product is the first EV charger to be powered directly by DC-source electricity.

The startup has already secured orders for its technology. The company is supplying its long-dwell-time 25kW DC-to-DC EV charger to a large logistics company to power its newly electrified delivery fleet.

Enteligent said that traditional fleet charging infrastructure uses AC Level 2 chargers that require significant engineering planning, long permitting wait times, and high costs. Furthermore, AC charging relies on the vehicle’s onboard AC/DC converter to charge its DC battery, which wastes 10% to 20% of the energy through conversion losses and is often limited to charge rates of 9.6 kW or less.

The company said its direct DC product leans on the inherent efficiency and reliability of DC technology. It avoids the energy conversion losses and equipment costs associated with converting solar energy from DC to AC and back again, which reduces overall expenses and makes clean energy more effective and affordable.

Entligent also manufactures solar rapid shutdown devices, module level power electronics, and other solar balance of systems components.

“Enteligent’s technology sets a new standard in maximizing solar energy efficiency,” said Jonathan Hannam, managing partner at Taronga Ventures. “Their holistic approach to solar power optimization offers practical solutions with real-world applications that meet the needs of global real asset owners and operators. Together, we can significantly advance decarbonization efforts for real assets.”

Natron Energy, manufacturer of sodium-ion battery energy storage systems, announced it will open a $1.4 billion factory in North Carolina.

The manufacturing facility is a planned 24 GW annual production capacity site in Edgecombe County. Once operational, the factory will increase Natron Energy’s production capacity by a factor of 40.

Natron’s batteries are the only UL-listed sodium-ion batteries on the market today, said the company. The batteries are expected to serve a wide range of use cases, including industrial power space, including data centers, mobility, EV fast charging, microgrids, and telecom, among others.

Natron Energy said its battery chemistry presents zero strain during charging and discharge, 10x faster cycling than traditional lithium-ion batteries, and 50,000+ cycle life, and are made without any lithium, cobalt, nickel, or other difficult-to-obtain minerals.

The company said its patented “Prussian blue electrodes” store and transfer sodium-ions faster and with lower internal resistance than any other commercial battery on the market today. 

The project is expected to create 1,000 full-time jobs in the area. The facility is nearly 1.2 million square feet, located on a 437 acre plot in Kingsboro. The factory is expected to be supported by over $50 million in grants from North Carolina.

“After evaluating over 70 sites across 9 states, we found that North Carolina, with its leadership in the clean energy revolution, would make the perfect home for this project. We are proud to partner with the state on this ambitious project to deliver high-quality jobs to the community while advancing the electrification of our economy,” said Colin Wessells, founder and co-chief executive officer, Natron Energy.

The factory is facilitated in part by a Job Development Investment Grant (JDIG) approved by the state’s Economic Investment Committee. Over the course of the 12-year term of the grant, the project is estimated to grow the state’s economy by $3.4 billion.

Natron and the state also anticipate additional support being provided for the project through the first use of the North Carolina Megasite Readiness Program, a new state grant program open to local governments and designed to provide funds to help prepare or upgrade qualifying industrial sites to the competitive level required in today’s economic development marketplace. The state expects Edgecombe County will apply for a $30 million grant from the fund.

“We’re proud to be leading the charge in the advancement of a domestic battery supply chain, and we’re grateful for the partnership of local and state officials here in North Carolina,” said Wendell Brooks, co-chief executive officer, Natron Energy.

Community solar developer Pivot Energy announced it has entered a five-year agreement with Microsoft to deploy up to 500 MW of community solar projects. The projects are planned to be developed in locations across the United States between 2025 and 2029.

Over 20 years, the 500 MWac is expected to produce more than 1 billion kilowatt hours of electricity annually, which is enough energy to power approximately 90,000 homes a year. This is equivalent to removing approximately 165,000 gas-powered passenger vehicles off the road each year, said Pivot Energy.

The agreement is Pivot’s largest renewable energy credit (REC) agreement to date. It also marks Microsoft’s first major distributed generation portfolio investment. Microsoft will purchase RECs generated by the projects for a 20-year term. By matching customer electricity usage with new renewable electricity generation, Microsoft supports its goal of reducing Scope 3 emissions by more than half by 2030.

Pivot will develop approximately 150 solar projects in 100 communities across 20 states, including Colorado, Maryland, Illinois, Delaware, Pennsylvania, and Ohio. The first projects are expected to come online this year.

“We believe the clean energy transition can and should benefit communities across the United States that have been historically excluded from economic opportunity,” said Adrian Anderson, general manager, renewables, Microsoft. “Through our work with Pivot Energy and with its commitments to driving community impact, this collaboration helps to build more inclusive, local economic growth across 100 communities while addressing the sustainability needs and opportunities within those communities.”

The agreement outlines four overarching community-centric initiatives that Pivot said it will prioritize:

1) Increasing the diversity of its subcontractors.

2) Partnering with workforce development organizations and subcontractors to train and hire local diverse talent.

3) Partnering with Sustain Our Future Foundation to invest in equitable community initiatives.

4) Increasing the energy bill savings of the community solar projects directed to low-income subscribers.

“An economy fueled by clean, distributed energy can do more than provide power at low cost; it drives growth and success in communities across the nation,” said Tom Hunt, chief executive officer, Pivot Energy.

ChargePoint, a provider of one of the largest EV charging networks in the United States, introduced Omni Port, an electric vehicle charging connector solution designed to be compatible with all major EVs.

Omni Port eliminates the hassle of carrying a charging adapter or having to dedicate parking spaces for different charging types. The port is available at no incremental cost, the company reports, and is now a standard feature of ChargePoint products.

“With Omni port, ChargePoint solved the challenges associated with a multiple connector environment, ensuring Tesla and non-Tesla drivers can continue to expect a world-class driver experience,” said Rick Wilmer, chief executive officer, ChargePoint.

ChargePoint designed the charging station to seamlessly adapt to each EV. Drivers enter their vehicle’s make and model into the ChargePoint app, tap to charge, and the charging station automatically releases the correct connector type. For users that would prefer not to use an app, a credit card payment option is available at the station.

Omni Port is built into both AC and DC charging stations. The charger enables full support for vehicles with 800 volt architecture, enabling max charging speeds for sustained periods.

The are more than 5.5 million EVs on roads in North America, more than half of which are equipped with J1772 or CCS1 charging ports. As automakers attempt to align on a single connector type for the future, these 5.5 million drivers need assurance that they will be able to charge when they need to. Omni port gives drivers and station owners peace of mind by combining these most common connector types into a single solution.

ChargePoint said Omni Port will begin to ship by the end of 2024. It can be retrofitted on ChargePoint CP6000 and Express Plus Power Link 2000 models at a “nominal cost.”

DCE Solar announced its Eco-Top rooftop solar mounting structure has achieved UL 3741 certification, placing the product in compliance with National Electric Code (NEC) 2020 standards.

The Eco-Top rooftop mount structure is designed for commercial and industrial rooftops. It is a ballasted racing system with durable recycled rubber ballast pads. DCE Solar said the mounts are designed to be roof-friendly, protecting the integrity of a roof by leveraging aerodynamics and structural performance to minimize roof loading. The mount uses recycled rubber ballast pads that limit vibration and protect the roof membrane and uses decreased ballast blocks and attachment counts to limit roof penetration and damage.

DCE Solar said its system requires five times fewer mechanical attachments and ballast blocks, resulting in material and labor savings of $0.03 to $0.06 per watt.

The company offers two main options – the Eco-Top High Density, which increases capacity by up to 20% with more wattage per square foot, and the Eco-Top-MR for metal roofs.

All structural components are constructed from g115 galvanized steel. An integral wind deflector minimizes system loading and also functions as a ballast tray, providing a location to place ballast in the array.

The structure is fastened via serrated flange heads. It has built-in vibration resistance and integral grounding and bonding, and all nuts are wax coated to eliminate galling.

The structure is rated for an average dead load of 3.5 psf, or 90 mph wind. It enables flat, 5 degrees, or 10-degree angle tilt. It has a 14 inch or 18 inch shade spacing. The Eco-Top mount supports all major module brands.

“Passing the UL 3741 certification for our Eco-Top Roof-Top solution underscores our dedication to safety, innovation, and efficiency in the solar industry,” said Bill Taylor, chief executive officer, DCE Solar. “This certification not only validates the quality of our product but also provides our customers with the confidence that they are investing in a top-tier, secure solar solution.”

DCE Solar is a U.S. manufacturer of solar ground-mounts and roof-mounted racking systems, founded in 2009. Find a product sheet for the Eco-Top here.

Ebon Solar, a Delaware-based solar cell manufacturing company, released a joint announcement with New Mexico Governor Michelle Lujan Grisham that it will open a manufacturing facility in the Southwest.

New Mexico, which has become a center for advanced manufacturing particularly for silicon computer chips, will now become home to an Ebon Solar facility spanning 834,000 square feet.

Over $942 million will be invested to create the facility, which is expected to generate 900 full-time jobs. The project is developed in Albuquerque’s Mesa del Sol industrial development area.

The Albuquerque Regional Economic Alliance (AREA) served as a key project management partner throughout Ebon Solar’s market evaluation process, facilitating many visits, interviews, and data analysis of the region and site selection support.

“We are thrilled to welcome Ebon Solar to the market; it not only represents a significant capital investment and new jobs to the community but aligns with PNM’s sustainability goals,” said Don Tarry, president and chief executive officer of electric utility PNM and the 2024 AREA Board Chair.

The Ebon Solar factory addresses a critical early upstream stage of the solar panel supply chain. Solar panels are made in a process from raw polysilicon mining, to refining into ingots, cutting into wafers, manufactured into cells, and finally assembled as modules.

While module assembly plants are opening in droves in the United States, with total cumulative capacity growing 71% nationwide in Q1 2024 alone, the need for earlier stages of the chain to be addressed becomes clear. However, cell manufacturing and other early-stage manufacturing processes are quite expensive to build and operate, as evidenced by Ebon Solar’s nearly $1 billion price tag.

(Read: “Can the U.S. fill its domestic solar supply chain gaps?”)

“Ebon Solar is proud to be an innovator in technologies that support renewable energy,” said Judy Cai, chief executive officer, Ebon Solar. “The choice of Albuquerque for our investment aligns with our commitment to sustainable innovation, and New Mexico offers abundant solar resources, favorable renewable energy policies, and a dedicated, skilled workforce.”

Wood Mackenzie released a report updating the current market size of community solar in the United States. The firm forecasts that community solar installed capacity will essentially double in five years.

Community solar typically involves a customer subscribing to a portion of an off-site solar facility’s generating capacity, receiving credits on their utility bills for the electricity produced by the facility.

Wood Mackenzie forecasts that 7.3 GW of community solar will be installed through 2029, bringing the cumulative total to over 14 GW that year. The firm forecasts a national growth rate of 5% through 2026 and an 11% contraction through 2029.

The U.S. community solar market has tripled in size since 2020, but growth is beginning to slow in existing state markets, said Wood Mackenzie.

“Additionally, the May 2024 decision on California community solar resulted in a significant 14% reduction to Wood Mackenzie’s five-year national outlook. Without a major market entrant like California, long-term community solar growth will largely depend on the enactment of legislation to enable new state markets,” said Caitlin Connolly, senior research analyst at Wood Mackenzie, and lead author of the report.

Under a bull case forecast, the firm’s expectation increases by 21% in existing markets, while the bear case projects a potential 20% decrease. These alternative scenarios do not account for the establishment of new state markets, such as Ohio, Pennsylvania, Michigan, and Wisconsin – all of which have significant interest and pre-development project pipelines. These markets would result in at least a 17% increase from the base forecast, reaching 17.1 GW installed in 2029, said Wood Mackenzie.

Community solar developers are continuing to navigate federal incentives.

“The fruits of the Inflation Reduction Act are numerous but difficult to count on,” said Connolly. “Community solar stakeholders are navigating a steep learning curve while trying to secure tax credit adders. In addition, awards from the $7 billion ‘Solar for All’ fund were announced in April 2024. Final implementation plans are not confirmed but developers hope to utilize federal funds to expand into new state markets even in the absence of official state programs.”

Wood Mackenzie expects 3.6 GW of community solar will serve low- to moderate-income households by 2029. Currently, about 829 MW of community solar serves LMI customers.

“The share of community solar capacity serving LMI subscribers grew from 2% in H2 2022 to 12% in H1 2024,” said the report. “Given the availability of the LMI tax credit adder, Solar for All funding, and evolution of state-level LMI requirements, the share of community solar dedicated to LMI subscribers will grow to nearly 25% by 2025.”

The top three community solar subscription managers cover 56% of subscribers an 71% of LMI subscribers. LMI subscribers remain the most costly to acquire with costs averaging $113 per kilowatt, 27% higher than the average cost to require non-LMI residential subscribers, said Wood Mackenzie.

The Global Polysilicon Marker (GPM), the OPIS benchmark for polysilicon outside China, was assessed at $22.567/kg this week, reflecting stable market fundamentals.

Industry insiders in the global polysilicon market are currently upset by the news of a delay in the preliminary ruling results of U.S. investigations into imported cells and modules from four Southeast Asian countries.

According to a source, the deadline for the countervailing duty investigation, originally expected around July 18, has been delayed to September 30. The preliminary results of the antidumping duty investigation, initially expected at the start of October, are now anticipated to be delayed by a week, with the possibility of further extension until the last week of November.

Other sources concurred, with one noting that “being postponed to November is a high probability event.” It is highly likely that the U.S. will wait until after the 2024 presidential election to release the specific results of the tariffs, the source added.

Another industry insider noted that the uncertainty surrounding major integrated manufacturers exporting modules to the U.S. has prompted them to consider every way possible of postponing their monthly purchases of global polysilicon secured with suppliers under long-term contracts during this period.

Uncertainty about the operations of these major enterprises has also intensified as a result. “Given that high gross margins from U.S. module prices are currently the only significant source of potential profitability for supply chain manufacturers, they can’t afford to abandon this market, despite the increasing trade barriers,” said an industry insider. The source added that more module manufacturers are reportedly delivering small module orders by paying a deposit at U.S. customs during this window.

The global polysilicon market is poised to endure another two to three months of a prolonged “winter chill”, a market observer concluded, noting that during this period, minimal price fluctuations are anticipated due to subdued market activities.

A market observer offered a long-term perspective, suggesting that with the support of U.S. trade policies, demand for global polysilicon should remain steady in the coming years. The next major factor likely to influence global polysilicon prices will be changes in the supply-demand dynamics between global polysilicon production and newly established ingot capacities outside of China and the four Southeast Asian countries – a shift that may only become significant after a few years.

China Mono Grade, OPIS’ assessment for mono-grade polysilicon prices in the country, remained steady at CNY 33/kg ($4.60/kg) this week, marking the tenth consecutive week of stability. China Mono Premium, OPIS’ price assessment for mono-grade polysilicon used for N-type ingot pulling, is reported at CNY 39/kg ($5.44/kg). Sources indicate that Chinese polysilicon manufacturers are still grappling with ongoing production cuts and persistent cash losses.

According to an upstream source, a major Chinese polysilicon producer with an annual capacity of 300,000 mt has scheduled only 13,000 mt for August. Similarly, another leading manufacturer of comparable scale plans to produce 8,000 mt in August.

Recent market consensus suggests that polysilicon prices have bottomed out and are unlikely to decline further, leading to reports of wafer companies and traders beginning to stockpile polysilicon.

According to a market participant, wafer companies are increasing their price inquiries for polysilicon, and some with stable cash flow have expressed intentions to stockpile, although no concrete actions have been observed yet.

“A slight rise in offers from some polysilicon manufacturers has already been seen this week, though this increase has not yet impacted actual transaction prices,” the source added.

Spot and futures traders have also boosted their inquiries concerning polysilicon prices. Multiple sources have disclosed to OPIS that China’s polysilicon is set to be listed as a futures commodity in October. This development could prompt some traders to hoard and build inventories, potentially driving up polysilicon prices.

Nevertheless, according to a market survey done by OPIS, there are still some industry insiders skeptical that listing polysilicon as a futures product will have a major positive impact on price increase.

“Given the current supply and demand scenario, I believe that listing polysilicon as a futures commodity will not result in a major increase in pricing, as the difficulty of driving up polysilicon prices is matched by the challenge of reducing polysilicon inventory,” a market source commented. “At the moment, the polysilicon inventory of 200,000 to 300,000 mt is massive, and it is improbable that all of it would be hoarded by dealers; not to mention that polysilicon production is still ongoing.”

Another market source offered a different perspective, noting that the success of listing polysilicon as a futures commodity also hinges on support from major polysilicon producers. If current low prices persist, these leading producers could potentially drive smaller competitors out of the market. However, listing polysilicon as a futures commodity might absorb surplus production capacity, potentially leading to a price rebound and providing a lifeline to smaller producers – a scenario that major producers are currently hesitant to support.

In the early stages of listing a product as a futures commodity, market operations are often underdeveloped, a market veteran commented, adding that this is particularly true for polysilicon, a product with only a few market participants and easily manipulated prices. “Given the current inactivity in the polysilicon market, it may not be an ideal time for a futures commodity launch, thus a major price shift is not predicted,” the source concluded.

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.

Microvast Holdings, a battery designer, developer, and manufacturer, announced a new energy storage system product called the ME6.

The ME6 is a high energy density lithium ferro-phosphate (LFP) containerized battery system that carries 6 MWh of power in a 21-foot container.

Microvast has a long history of developing nickel manganese cobalt (NMC) batteries for commercial vehicle customers. The new 565 Ah LFP-based batteries are optimized for stationary energy storage system customers.

“Energy storage is essential for carbon reduction and accelerating the global transition to clean energy. Our ME6 energy storage solution can be used for any application where electric energy supply is needed,” said Yang Wu, chief executive officer of Microvast.

The containerized battery has a lifecycle exceeding 10,000 cycles and up to a 30-year lifespan, said the company. It is IP55, and C4 rated for safety and contains nitrogen-based protection systems to prevent fires.

The ME6 includes an integrated modular cooling system, which extends battery life and enhances round-trip efficiency.

“Our integrated modular liquid cooling system helps ensure consistent battery temperatures, optimizing performance through active cell balancing and enhancing round-trip efficiency while reducing heat loss,” said Dr. Wenjuan Mattis, chief technology officer, Microvast.

Microvast said its LFP solution offers a lower-cost alternative to NMC batteries. The batteries do not contain cobalt, making them a more sustainable choice for large-scale renewable energy operations.

With this new product announcement from Microvast comes a shift in regional operations. The company will close its Colorado manufacturing facilities and focus solely on producing LFP batteries at its Clarksville, Tennessee facility. Microvast said its products are expected to qualify for the IRA Section 45X advanced manufacturing tax credit.

“ME6, the latest generation of our energy storage solutions, is engineered for enhanced efficiency,” said Mattis. “Utilizing our high-performance LFP cells, we have developed a ME6 container that boosts capacity and stability while providing an exceptional lifespan of up to 30 years and supporting more than 10,000 cycles.”

The U.S. Department of Energy (DOE) Loans Programs Office (LPO) announced a conditional commitment for a loan guarantee of up to $1.45 billion to Qcells to support its North American solar manufacturing expansions.

The loan guarantee is offered through LPO’s Title 17 Clean Energy Financing Program, which includes financing opportunities for innovative energy and supply chain projects and projects that reinvest in existing energy infrastructure.

The company is developing a solar ingot, wafer, cell, and solar panel manufacturing facility, supplying each stage of the solar supply chain from raw polysilicon to end-user components. The facility, located in Cartersville, Georgia, will be the largest ingot and wafer plant in the United States, addressing critical early stages of the supply chain.

Once fully operational, the facility is expected to produce 3.3 GW of solar panels per year. This is roughly enough solar capacity to power half a million U.S. households, said the company. It is also equivalent to reducing emissions from power generation by more than 5 million tons of carbon dioxide per year.

The project is expected to support 1,200 construction jobs and, upon completion, 1,950 full-time operations jobs. Approximately 40% to 50% of the construction work has been awarded to local contractors, including contractors from Atlanta, Georgia and Chattanooga, Tennessee. According to an economic review by the Cartersville-Bartow County Department of Economic Development, the investment will create nearly 6,800 jobs in Bartow and Whitfield Counties and has a potential sales output of more than $2 billion.

Panels produced at the site will be designed for both distributed and utility-scale applications. Qcells is also among the largest utility-scale project developers for both solar and storage in the United States with over 2 GW of projects developed or constructed and a project development pipeline of over 10 GW. The company has entered into an 8-year, 12 GW solar and engineering, procurement, and construction (EPC) agreement with Microsoft to be fulfilled with solar panels made in Cartersville.

Components produced by the project are expected to benefit from the 45X Advanced Manufacturing Production Tax Credit. Qcells’ products produced at the site are also expected to contribute to project eligibility for the domestic content 10% tax credit bonus.

“Since IRA’s passage, over 325 GW of manufacturing capacity has been announced across the solar supply chain, representing more than 31,000 potential jobs and nearly $16 billion in announced investments across 111 new facilities or expansions,” said a press release from DOE.

While this conditional commitment indicates DOE’s intent to finance the project, DOE and the company must satisfy certain technical, legal, environmental, and financial conditions before the Department enters into definitive financing documents and funds the loan.

Global solar inverter provider GoodWe announced a new inverter product line for small commercial and industrial (C&I) solar projects called the LVSMT-US inverter.

The inverter is designed to be easily calibrated during commissioning to a range of sizes and voltage outputs, including 22/28kW 208V, 23/30kW at 220V, and 25/32kW at 240V.

“The massive convenience that the voltage and capacity flexibility of this inverter offers is truly groundbreaking,” said Michael Mendik, country manager, GoodWe USA and Canada.

GoodWe uses the same string inverter technology as its SMT-US series for medium to large C&I installations while enhancing safety features.

LVSMT-US is a three-phase, low-voltage inverter with four maximum power point trackers (MPPT). It contains a rapid shutdown transmitter to meet safety requirements without the need for additional module-level hardware.

The inverter sports a maximum efficiency of 97.5% and a wide voltage operating range of 180V-950V, and 180% DC oversizing. It has a smart shadow scanning feature that can be activated in the event of temporary shade, removing the need for module level power electronics (MLPE).

GoodWe’s inverter includes Type II Surge Protection on both the DC and AC side, integrated AFCI, and the NEMA Type 4X rating.

“Following the success of our SMT-US series for medium- to large-scale C&I installations, we are bringing its advanced string-inverter technology to the small C&I market,” said Mendik. “From carports and schools to healthcare settings and retail establishments, this value-packed string inverter eliminates the need for costly MLPE, while still providing all of the benefits to improve the energy and financial performance over the system’s lifetime.”

GoodWe’s commercial and industrial product suite includes inverters, smart meters, and loggers for monitoring. The company is headquartered in China and listed on the Shanghai Stock Exchange. It has nearly 5,000 employees and a track record of over 71 GW of installation in over 100 countries as of the end of 2023.

Sunrun (Nasdaq: RUN) delivered its Q2, 2024 earnings, meeting analyst expectations for revenue and delivering promising guidance for cash generation in 2025. 

The residential solar and energy storage provider reported $524 million in revenue for the quarter, in-line with Wall Street expectations. The company delivered a surprise earnings per share of $0.55, up from the expected loss ($0.40). The stock is trading up roughly 15% during the trading session post-earnings report.

For businesses in the residential solar industry, generating cash and cover debts has become an area of focus for investors. Sunrun had a strong performance in this area, generating $217 million in cash in Q2. The company reiterated its guidance of $50 million to $125 million in cash generation in Q4 and introduced guidance of $350 million to $600 million in 2025. 

Sunrun added 26,687 customers in the second quarter, about 94% of which were lease or power purchase agreement customers. Annual recurring revenue from subscribers was approximately $1.5 billion as of June 30, 2024. 

Net earning assets increased to $5.7 billion, including over $1 billion in total cash. 

Sunrun posted strong execution in capital markets, as well, closing an $886 million securitization of residential solar and battery systems. The two classes of non-recourse Class A senior notes were rated A+ by Kroll with the $443.15 million public Class A-1 note priced at a credit spread of 205 basis points. The Class A notes represented an advance rate of approximately 72.6%. 

Energy storage capacity installed reached 192 MW in Q2, reaching prior expectations. Sunrun now has 7.1 GW of networked solar energy capacity. 

“In the second quarter we again set new records for both storage installation and attachment rates, further differentiating Sunrun in the industry, beating the high-end of our storage installation guidance and delivering solid quarter-over-quarter growth for solar installation, Cash Generation and Net Subscriber Value,” said Mary Powell, Sunrun’s Chief Executive Officer. 

Energy storage attachment rates increased to 54%, up from 18% in the same period in 2023. Sunrun has now installed more than 116,000 solar and storage systems, representing nearly 1.8 GWh of stored energy capacity. 

Sunrun also launched a partnership with Tesla to support the Texas power grid. More than 150 Sunrun customers have enrolled in a virtual power plant (VPP) program to be compensated for dispatching electricity from their batteries to the grid when power is needed most. Additionally, during prolonged power outages in the aftermath of Hurricane Beryl, more than 1,600 Sunrun customers in the greater Houston area were able to keep their homes energized with more than 70,000 hours of backup energy provided by their solar-plus-storage systems.

Dawsonville, Georgia motorsports club Atlanta Motorsports Park announced it is installing solar to support its operations.

Atlanta Motorsports club hosts an F1-style road course and a karting course. The company is expected to power about 60% of its operations with the new solar project, designed and set to be installed by Hannah Solar. Five buildings will be powered by the array. The project is expected to complete installation in Q3 2024.

“The ability to generate over half of our energy needs through solar pushes us closer to our vision of making AMP’s campus its own self-sustaining community and resort,” said chief executive officer Jeremy Porter.

The array contains 747 panels with 480 W power, adding 358 kW solar onsite. This is the equivalent power demand of about 300 homes.

The investment follows on the motorsports club’s investment in electric vehicle charging, including ten level 3 DC superchargers, and eight level 2 chargers. The company has also installed all LED lighting, solar powered CCTV/Signs, on site water/wastewater treatment, and efficient fixtures.

Hannah Solar procured solar panels for the project from Qcells, which operates a large solar panel manufacturing facility locally in Georgia.

The installation can generate 450,300 kWh of electricity annually, offsetting an estimated 7,312 pounds of CO2 emissions over a 30-year period. This offset is equivalent to eliminating over 16.6 million miles of road vehicle travel, or akin to planting 109,600 trees, based on an impact estimating tool from the Environmental Protection Agency.

The project was able to recoup 50% of its total costs through the a grant from the Department of Agriculture’s Rural Energy for America Program Renewable Energy Systems (REAP) program. The program provides guaranteed loan financing and grant funding to agricultural producers and rural small businesses for renewable energy systems or to make energy efficiency improvements. Agricultural producers may also apply for new energy efficient equipment and new system loans for agricultural production and processing.

Residential solar company SunPower (Nasdaq: SPWR) has filed for bankruptcy.

“SunPower has faced a severe liquidity crisis caused by a sharp decline in demand in the solar market and SunPower’s inability to obtain new capital,” said Matthew Henry, chief transformation officer, SunPower.

The residential solar industry in the United States has been struggling over the past two years as rising interest rates and regulatory changes have squeezed the value offered to customers. As demand fell, rising excess inventory posed further challenges for installers.

Industry-wide, installations are down roughly 20% nationwide in 2024. SunPower joins Titan Solar Power and Sunworks as publicly-traded residential solar installers that have gone under this year, along with many smaller installers, particularly in California. However, analysts have cautioned that the industry is not in a tailspin as it may appear.

“SunPower’s travails are emphatically a company-specific issue and should not be seen as a comment on the underlying demand for U.S. residential solar,” Pavel Molchanov, an analyst with Raymond James.

SunPower’s struggles continued through persistent high interest rates. In December 2023 the company defaulted on its debt and issued a warning that it had “going concerns” about remaining in business. In April, the company announced it would close numerous installation service centers across the country and cut about 26% of its workforce.

This July, SunPower communicated to its employees that it will pause several core operations. The company announced it will deactivate its lease and power purchase agreement offerings and will discontinue new product shipments.

SunPower will now sell its assets, including installation company Blue Raven Solar and its new homes unit to Complete Solaria, Inc. for $45 million. The company requested courts approve the deal by late September.

SunPower was one of the longest-running solar businesses in the United States, formed in 1985. The company spun off its manufacturing business in 2020 to focus more squarely on rooftop solar as demand surged. Since then, demand cooled considerably, and, under a high interest rate environment, the strategy proved fatal for the company.

The U.S.-based SunPower is not to be confused with the SunPower branded solar panels designed, manufactured, and sold by Maxeon Solar Technologies in Europe and elsewhere outside of the U.S. and Canada. “Other than a product brand name, there is no existing relationship between Maxeon and SunPower Corporation”, a spokesperson from Maxeon Solar told pv magazine.​ SunPower Corp. and Maxeon separated in August 2020 when Maxeon spun off as an independent company. Maxeon previously had a supply agreement to provide solar panels to SunPower Corp., “but that agreement was terminated in 2023, and since Q1 2024, Maxeon has not been shipping any product to SunPower Corp”, she concluded.

NASA installed the solar array for the Europa Clipper spacecraft, a robotic craft with a mission to reach Jupiter’s moon Europa by 2030. The large moon is one of 95 that orbit Jupiter, and it is studied closely due to its potential to host life in its global liquid ocean underneath its icy surface. 

Europa Clipper will be the largest spacecraft NASA has ever developed for a planetary mission. The craft is outfitted with large solar arrays that will serve as the primary power source for the mission. The arrays are large, as the Jupiter system is more than five times as far from the sun as Earth. 

The craft’s arrays are built as two five-panel wings. Each solar array measures 46.5 feet in length. To install the array, the team suspended the solar array on a gravity offload support system that helps support the weight of the solar array while it’s here on Earth. Next, NASA technicians will begin inspecting and cleaning as part of its assembly, test and launch operations. 

The array uses Azur Space 3G28 solar cells – with substrate panels from Airborne in the Netherlands, laid down by Leonardo in Italy and integrated into solar panels by Airbus Defence and Space in the Netherlands. The NASA Juice Mission also uses Azur Space 3G28 cells. 

The solar cells are designed for space travel, with self-annealing properties and the ability to operate under the intense radiation of space. More details can be found on an Airbus document.

The array is folded when launched and is designed for a passive deployment with spring-motorized hinges.

At launch, Europa Clipper will weigh approximately 13,000 lbs. Almost half of the weight will be fuel – nearly 6,000 lbs of propellant.

“Europa Clipper will launch in October 2024 on a SpaceX Falcon Heavy rocket from Kennedy Space Center in Florida. The spacecraft will fly by Mars, then back by Earth, using the gravity of each planet to increase its momentum. These so-called ‘gravity assists’ will provide Europa Clipper with the velocity needed to reach Jupiter in 2030,” said NASA.

Goldman Sachs announced it has invested $440 million under its Alternatives fund in BrightNight, a renewable power company providing solutions to utility, commercial, and industrial customers.

BofA Securities, Inc. and PJT Partners acted as financial advisors to BrightNight. Jefferies LLC acted as sole financial advisor and Weil, Gotshal & Manges served as legal counsel to Goldman Sachs Alternatives. The transaction is expected to close this September.

The funds are expected to help BrightNight advance its five-year business plan and execute a 31 GW renewable power portfolio. A proprietary AI software program, PowerAlpha is used to support the management of the company’s portfolio.

“We have quickly established a large and differentiated portfolio in high-demand growth markets seeking decarbonizing renewable energy solutions to meet growing load and reliability needs,” said BrightNight chairman and chief executive officer Martin Hermann.

Goldman Sachs said the two entities share a joint ambition to build a leading renewable independent power producer (IPP). The investor said it will provide long-term capital backing and leverage relationships in the sector to support BrightNight.

“Demand for renewable energy continues to benefit from strong secular energy transition tailwinds, including substantial corporate decarbonization goals and both federal and state-level policy support,” said Teresa Mattamouros, managing director in Infrastructure at Goldman Sachs Alternatives. “We have been impressed by BrightNight’s unique development approach, focusing on markets with attractive commercial dynamics and targeting high-value interconnection positions.”

Along with Goldman Sachs, investor Global Infrastructure Partners will continue its existing capital commitments to fund construction equity needs and will also maintain its minority equity interests.

Nextracker (Nasdaq: NXT), a U.S.-based solution provider of solar trackers and software, posted its earnings for Q1 fiscal year 2025.

For nine consecutive years, the company stands as the global market leader in solar tracer solutions for utility-scale tracers based on GW shipped, according to Wood Mackenzie.

“Our products enable solar panels power plants to follow the sun’s movement across the sky and optimize plant performance. With power plants operating in 40 countries worldwide, Nextracker offers solar tracker technologies that increase energy production while reducing costs for significant plant ROI,” said the company in a letter to shareholders.

The company recorded strong growth, closing Q1 FY25 revenues of $720 million, up 50% from the $480 million in revenue in Q1 FY24.

Adjusted EBITDA for the quarter was $175 million, up 109% from the previous year’s adjusted EBITDA of $84 million. Adjusted EBITDA included $47 million of benefits from the Inflation Reduction Act’s 45X manufacturing tax credit.

This marks the sixth consecutive quarter of double-digit revenue growth year-over-year since Nextracker’s initial public offering. Most of the company’s Q1 revenue was in the United States (71% of total), reflecting a strong 90% year-over-year growth in U.S. revenues.

Nextracker’s Q1 gross profit increased year-over-year from $114 million in FY24 to $237 million in FY25. Its operating income increased from $82 million to $184 million and adjusted diluted earnings per share nearly doubled from $0.48 to $0.93. The company posted an adjusted free cash flow generation of $118 million in Q1 and $319 million for trailing twelve months.

The company’s order backlog continues to grow, increasing quarter-over-quarter and now standing at over $4 billion.

Business highlights:

• Launched NX Horizon Low Carbon Tracker in April 2024, the industry’s first low-carbon tracker solution
• Unveiled agrivoltaic solution in July 2024, including a suite of AgriPV solutions for agricultural and ranching sites
• Expanded JM Steel’s Pittsburgh facility with Nextracker-dedicated manufacturing in April 2024
• Opened a second Nevada factory by Unimacts with Nextracker-dedicated manufacturing in June 2024Acquired foundation specialist Ojjo in June 2024Acquired the foundations business of Solar Pile International (SPI) in July 2024
• Amended credit agreement and expanded revolver facility from $500 million to $1 billion on June 21, 2024Currently expect 100% U.S. domestic content capability with an early CY25 planned ship date

“Our fiscal year is off to an excellent start with another quarter of strong execution, where healthy demand dynamics continued for solar trackers in both the U.S. and international markets,” said Dan Shugar, founder and chief executive officer of Nextracker. “We also unveiled new product solutions, expanded several of our partner manufacturing facilities, and added foundations solutions with the acquisitions of Ojjo and Solar Pile International’s foundations business.”

Prices in the Chinese cell market were assessed lower week-to-week reflecting buy-sell indications. The FOB China Mono PERC M10 cell and TOPCon M10 cell prices were assessed down 2.64% at $0.0369/WW while the FOB China Mono PERC G12 cell prices were assessed lower by 3.29% at $0.0382/W week-to-week.

Market activity remained quiet as the majority of market participants continued to stay on the sidelines, adopting a wait-and-see approach. While prices had already reached their lowest point, falling 59-63% year-to-year on July 30, according to OPIS data, expectations of further price declines kept most buyers away from the market.

In the domestic market, some sellers had reduced prices of Mono PERC M10 and TOPCon M10 to CNY0.29 ($0.040)/W while others kept prices stable at CNY0.30/W. The prices of Mono PERC M10 and TOPCon M10 cells were assessed at CNY 0.298/W, down 2.3% week-to-week. Prices of Mono PERC G12 prices were lower by 3.1% at CNY0.308/W.

China produced a total of 310 GW of cells in the first half of 2024, an increase of 37.8% year-to-year despite attempts by cell manufacturers to reduce cell production in June and July in a bid to curtail the oversupply situation in the market.

Although cell exports for the same period rose 26.2% to 142.16 GW, achieved sales prices were much lower compared to a year ago, resulting in tighter margins for cell manufacturers, an industry source said. The industry is experiencing a stage of persistent low prices throughout the solar value chain and if this should continue for long, the industry could be headed for a consolidation faster than expected.

Meanwhile, cell manufacturers continue to cut production rates in a bid to restore market supply and demand balance. China’s cell production in July was expected to reach 49-51 GW, down from 53 GW in June, according to the Silicon Industry of China Nonferrous Metals Industry Association.

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.

Brookfield Renewable Partners announced it has filed a notice of intent to develop a 900 MW solar project in Oregon, making it among the largest solar projects in U.S. history.

The project is located near the Oregon Raceway outside of Grass Valley. It is placed next to existing transmission lines, eliminating the need for additional transmission infrastructure buildout.

Called Speedway Solar and Battery Storage Project, the proposed facility began community outreach efforts in the spring of 2024. Brookfield expects to issue a project order in fall 2024, apply for a site certificate in the winter of 2024, hold a public informational meeting in spring 2025, and deliver a proposed order in fall 2025. If approved, the project would receive a final order and site certificate in Spring 2026, after which the project can be constructed.

The project has a unique design in which the solar array is designed in “ribbons” along the edge of existing agricultural and wildlife corridors, thereby allowing for continued agricultural use of the land. Speedway Solar is expected to occupy about 4,500 to 6,000 acres.

“With Speedway, we want to preserve the county’s legacy of natural resource stewardship,” said John Soininen, vice president of development, Brookfield Renewables U.S. “By working with the landowners, we can reach our twin goals of decarbonizing the grid and maintaining the character of the region.”

During the construction phase, the project is expected to create hundreds of jobs and stimulate local economic activity. Once operational, it will provide ongoing employment opportunities and contribute to the local tax base for shared priorities like firefighters, education and infrastructure.

Find the website for the Sherman County, Oregon proposed project here.

Sunnova Energy International, a publicly traded home “adaptive services” company providing solar, energy storage, and home energy management services, announced it has formed two new partnerships with Tenet Energy and Finturf.

Tenet Energy is a financial technology platform focused on the energy transition, starting with electric vehicles. Tenet connects EV drivers and fleet owners with loan terms from sustainability-focused financial institutions.

The joint effort will include a series of exclusive promotions aimed at encouraging Sunnova customers to invest in an electric vehicle with Tenet’s financing options and Tenet customers to adopt Sunnova’s solar energy systems. The promotions will include special discounts and flexible finance terms.

“By using solar panels to charge electric vehicles, homeowners can achieve significant cost savings—potentially hundreds of dollars annually on their electric bills,” said Tenet. “This integration results in a lower overall total cost of ownership, offers a sophisticated smart home system that optimizes energy use and offers substantial economic benefits like reduced utility bills and lower fuel costs.”

Sunnova will also partner with and become a financing partner for Finturf, a multi-lender point-of-sale platform. The company will provide financing for HVAC systems, roofing, generators, EV chargers, and electrical panel upgrades.

Sunnova’s financing options range from $500 to $250,000, offering flexible terms from 12 months to 25 years and competitive APRs starting as low as 0%.

“Sunnova’s addition represents a significant milestone in advancing sustainable home improvement financing,” said Stephen Pool, vice president of partnerships at Finturf. “By integrating Sunnova’s energy-efficient financing options into our network, we’re empowering homeowners to pursue eco-friendly projects with ease and confidence.”

A flourishing new market has grown out of the key policy changes set forth by the Inflation Reduction Act (IRA) of 2022, making more capital available for clean energy developers. The IRA created a pathway for clean energy developers to sell their federal tax credits to third parties in exchange for cash, thereby accelerating investment. The first transactions under this new provision occurred in January 2023.

Tax credit transfer marketplace operator Crux released a mid-year Market Intelligence Report, noting a larger-than-expected market for tax credit sales in 2024. Crux tracked $6.8 billion specific transactions in the first half of 2024, corresponding to an estimated $9 billion to $11 billion of transactions closed so far this year nationwide. 

Crux said that by year’s end, U.S. clean energy tax credit transactions will total $20 billion to $25 billion.

The marketplace operator said that established technologies accounted for most of the transactions this year, with wind, utility-scale solar, energy storage, and advanced manufacturing credits accounting for 95% of the reported deals. Crux said that in the second half of 2024, distributed generation, residential solar projects, additional 45X manufacturing credits, and “renewable” natural gas (RNG) may participate and contribute to an even larger market size.

Solar had the largest share in supply of tax credits available, representing about 41% of the total. Solar and storage hybrid projects represented another 9% of total tax credit supply.

Pricing for the first half was “strong” according to Crux, with average Production Tax Credit (PTC) deals fetching $0.95 per dollar of tax credit value, $0.925 for Investment Tax Credit (ITC). This compares to $0.94 and $0.92 respectively in 2023.

Average deal size reported by Crux was $55 million for ITC deals and $85 million for spot PTC deals. In 2023 average deal sizes were $20 million and $60 million, respectively. Despite this, pv magazine USA has reported on smaller tax credit deals being made, suggesting that there is an appetite for tax credit sales of all sizes.

Crux said that deal size and insurance continue to play dominant roles in market pricing. Small to mid-sized deals valued between $5 million and $25 million saw lower average pricing than the market overall with $0.937 for PTC and $0.918 for ITC on average. It said the use of insurance in ITC deals, though common, tends to be correlated with lower pricing compared to deals with parent indemnification, especially for deals lower than $25 million.

The marketplace provider said buyers are now beginning to look out to 2025 tax credit deals, with data indicating that forward commitments tend to transact at a one to three cent discount to 2024 deals. About 25% of 2024 reported deals included a forward component, including a full or partial purchase of future year tax credits, said Crux.

“This market has continued to grow in size, technological diversity, and depth, driving billions of dollars of new private sector investments into energy infrastructure and domestic manufacturing,” said Alfred Johnson, co-founder and chief executive officer of Crux. “These investments have created jobs and driven a new wave of American technological innovation. We are seeing new participants enter the market every month, market standards taking shape, and all facets of the market becoming more transparent and efficient.”

The U.S. Department of the Interior announced that the Bureau of Land Management (BLM) is advancing nine solar projects on public lands that would add over 6 GW of combined electric generation capacity to the grid. Together, the projects would generate enough electricity to power roughly 2 million U.S. homes.

The BLM manages over 245 million acres of public land mainly in 12 western states, including Alaska. To date, the BLM has permitted more than 25 GW of clean energy projects, enough to power about 12 million homes. This includes solar, wind, and geothermal projects as well as gen-tie lines on public lands that are essential for connecting clean energy generation projects on both federal and non-federal lands to the grid.

“As we continue to review clean energy projects, we are committed to collaborating with states, Tribes and stakeholders to ensure that we are building lasting opportunities to create jobs and stimulate the clean energy economy,” said BLM director Tracey Stone-Manning.

The latest round of BLM project advancements include the Esmerelda 7 solar project, among the largest solar projects in the world. Esmerelda 7 is a set of seven proposed utility-scale solar facilities with battery energy storage systems near Tonopah, Nevada. The projects are proposed to be developed on 118,000 acres of BLM managed land.

BLM is now opening a 45-day public comment period on the draft environmental impact statement and resource management plan for Esmerelda 7. The environmental impact statement will provide the foundation for individual environmental analyses of each project, after which the BLM will decide whether to grant rights-of-way for some or all of the projects.

If all Esmerelda 7 projects are approved, the portfolio would add 5.35 GW of electricity, or enough to power about 1.6 million homes.

Along with the BLM-supported Esmerelda 7 is the Libra Solar project, a 700 MW solar and 700 MW battery energy storage project with a 24-mile generation tie-line, planned for development in Mineral and Lyon Counties in Nevada.

The BLM is also opening a 30-day public comment period for the Elisabeth Solar Project near Dateland, Arizona. The project would add 270 MW of solar and 300 MW of battery energy storage.

“With today’s advancement of nine solar energy projects on public lands, we are taking a significant step towards these efforts and President Biden’s ambitious clean energy goals,” said principal deputy assistant secretary for Land and Minerals management, Dr. Steve Feldgus.

As of July 2024, an additional 70 utility-scale clean energy projects are in process by the BLM throughout the Western United States. These projects have the potential to produce almost 32 GW of renewable energy. In addition, BLM has begun the preliminary review of approximately 166 applications for solar and wind development, as well as more than 40 applications for solar and wind energy site testing. 

The Biden-Harris administration has set a goal to achieve a carbon pollution free power sector by 2035.

From pv magazine Global

As the global energy landscape shifts towards renewable energy sources, effective reactive power management becomes critical for ensuring grid stability and reliability. The recent report by IEA PVPS Task 14, “Reactive Power Management with Distributed Energy Resources,” delves into state-of-the-art practices, best practices, and recommendations for managing reactive power amidst the growing integration of distributed energy resources (DERs). This article provides a comprehensive overview of the report’s findings, regulatory frameworks, and practical applications, underscoring the essential role of reactive power management in maintaining a stable and efficient power grid.

The Importance of Reactive Power Management

Reactive power management is essential for maintaining voltage control, ensuring high power quality, and enhancing overall grid stability. It helps prevent issues such as harmonics, flicker, unbalanced loads, and power oscillations, which can negatively impact power quality and the ability to transfer power effectively. With the increasing integration of DERs like photovoltaic (PV) systems, these resources must assume greater responsibility for providing reactive power control. This improvement in power system stability is crucial for preventing problems like load shedding and system collapse, ultimately enhancing the security and reliability of the power system.

Objectives and Purpose of the Report

The IEA PVPS Task 14 report aims to provide a management summary on the state-of-the-art practices, best practices, and recommendations for reactive power management. It explores regulatory frameworks in selected countries, highlighting diverse approaches to managing reactive power. The report offers insights into the current state and future prospects of reactive power management in the context of increasing DER integration and investigates the effectiveness of various regulatory frameworks in supporting reactive power management.

Regulatory Requirements and Practices

The report covers the regulatory requirements in selected Task 14 countries and research and application examples from these countries. It provides an overview of reactive power regulations across various countries, detailing grid codes and frameworks that shape the requirements for connected DERs to provide reactive power control. Task 14 exemplarily examines how these regulations influence the operation of power systems with increasing integration of renewable energy sources. As an example of the regulatory requirements, Germany will be mentioned in this article.

Example: Germany’s Grid Codes for DER Reactive Power Provision

In Germany, current grid codes mandate that DERs must provide controllable reactive power during feed-in times. The guidelines ensure that DERs contribute effectively to grid stability by providing necessary reactive power. This capability allows Distribution System Operators (DSOs) to utilize DER for additional system services. The requirements vary based on the voltage level:

• Low Voltage (LV): VDE-AR-N 4105 specifies that DER with a capacity of ≤4.6 kVA must provide reactive power with a minimum power factor of 0.95, while larger DER should provide a minimum power factor of 0.9.
• Medium Voltage (MV): VDE-AR-N 4110 requires DER to maintain reactive power within a fixed range when active power feed-in exceeds 20% of installed capacity, ensuring stability at the point of common coupling (PCC).
• High Voltage (HV): VDE-AR-N 4120 offers three options for reactive power provision based on the generator’s active power feed-in and capacity. Each variant specifies different overexcited and underexcited power factors, allowing DSOs to select the most suitable option for their specific needs. DSOs can select one of the suggested options based on the specific circumstances at the PCC of each generator. HV and extra high voltage (EHV) level generators must be able to provide reactive power within one of the fixed reactive power ranges if their active power feed-in exceeds 20% of their total installed capacity.

One common characteristic is that there are just minimal or no reactive power requirements when feeding in small active powers. The different demanded reactive power capabilities are summarized in Figure 1.

Selected Case Studies

In Germany, the case study focus is on forecasting the reactive power flexibility potential of medium-voltage (MV) PV plants. The study evaluates various PV forecasting approaches and introduces a reliability indicator to assess the accuracy of reactive power flexibility forecasts. This emphasizes the need for high reliability in forecasts to prevent overestimation and explores the use of a reactive power planning reserve to enhance forecast reliability. This especially corresponds to times of low active power infeeds as mentioned in the previous section and emphasizes the importance of continuous updates of grid codes as indicated in the Task 14 PV ancillary services report.

Japan’s approach involves evaluating voltage control performance under different scenarios, considering the increasing PV penetration. The study, conducted by a consortium involving TEPCO Power Grid and Waseda University, supported by NEDO, assessed voltage control under fixed power factor control. The findings led to a new grid code in 2023, stipulating that power factor settings must be adaptable based on DSOs’ requests, highlighting the need for flexible control strategies.

Austria’s study focused on the effectiveness of future network-related measures in low-voltage grids. It evaluated various scenarios, including the impact of climate policies, regional technology rollouts, and different operating strategies related to PV, heat pumps, and e-mobility. The study identified challenges such as the need for detailed analysis of Q(V) control contributions and the lack of large-scale grid simulation capabilities, which hinder a comprehensive understanding of reactive power management’s value in distribution grids.

Key Takeaways from the Report

The report’s main authors highlight three key takeaways. Firstly, there is a need for updated regulatory frameworks to align with the evolving energy landscape, ensuring the resilience and efficiency of power systems. Secondly, the potential of DERs as a source for reactive power services should be further explored, including enhanced integration of solar PV forecasting. Thirdly, collaboration between Transmission System Operators (TSOs) and DSOs is essential for effective reactive power management, which could be enhanced with Information and Communications Technology (ICT).

Conclusion of Task 14 and Future Directions

Task 14 has concluded after 14 years of successful research and development in the field of PV integration and reactive power management. Throughout its three phases, Task 14 has made significant strides in addressing technical challenges, developing standards, and promoting best practices for high penetration of PV systems in electricity grids. As Task 14 ends, its legacy continues to influence grid management and renewable integration strategies.

Looking forward, Task 19 will commence in 2025 as a follow-up to Task 14, building on its achievements and continuing the mission of enhancing grid stability and efficiency with increased renewable energy integration. Task 19 will focus on managing grids with 100% renewable energy sources, integrating solar PV with wind, and defining the role of solar PV in the smart grid.

Find more information on IEA PVPS Task 14 and all of their publications here.

Q. When did you install energy storage? Was it part of a solar project?

In December 2019. I installed a single battery along with 25 solar panels on my roof.

Q. Did the project have an EV charger included?

Yes, I also installed an EV charger at the same time. I bought a Tesla Model 3 in June 2019. Until the EV charger was installed, I was driving to a nearby Supercharger to charge my car. Now I charge mostly at home.

Q. What brand of storage do you use?

I went with an LG Chem battery. It was a choice between a Tesla Powerwall and an LG Chem battery. The Powerwall had more storage capacity but was substantially more expensive.

Q. How did you decide on the size of the battery you needed?

I went with the solar installer’s recommendation and installed a single battery.

Q. Why did you include energy storage?

I installed it for two reasons: to power essential circuits in the house during power outages and to engage in arbitrage against a three-period time-of-use rate, EV-A rate. It had much lower off-peak prices than the standard TOU rate.

Q. What functions do you use the battery for?

Every day the battery is used for TOU arbitrage. It is charged every morning by the solar panels while the house is powered by the grid at the off-peak rate. After the battery is fully charged, the solar panels power the house. That usually begins in the late morning hours and continues until the early afternoon hours. When the solar panels are not generating enough power to meet the needs of the house, the battery begins to send power to the house. That continues until the battery has dropped to 30% charge. Then it goes into standby mode, to supply power if an outage occurs.

On mild weather days, when the central air conditioner is not running, the battery can keep on powering the house until 10 or sometimes even 11 pm. In the summer, the battery stops charging the house around 6 or 7 pm.

Q. How often do you have power outages? What kind of problems do they cause?

From June 2021 onwards, I have had more than a dozen power outages. Usually they are just a few hours long. The battery kicks in and runs five essential circuits, including the refrigerators, the freezer, lights and numerous plug loads.

I have now added a sixth circuit, which supplies power to the gas furnace. I did that when we had a couple of outages during the winter months. Both lasted longer than 10 hours. One was a planned outage for repairs to the underground wiring that we have in our neighborhood. It was followed two days later by an even longer unplanned outage. During those days, the gas furnace was not getting power and it did not run. The temperature in the house dropped to 60 degrees.

Q. Has the battery suffered degradation? Has it needed repairs?

Slight degradation seems to have occurred. It’s rated at 9.8 kWh but I don’t think it is storing that much power now, four and half years after installation. The only repairs that were needed were when it was just a month old. An installation error occurred, and the battery died. A replacement was installed a couple of months later.

There was also a problem with the two “strings” that connect the solar panels with the inverter. One of them was inadvertently disconnected when the contractor came by to check why my net usage data from the inverter did not line up with the data in my monthly PG&E bills. I was quite despondent. Thankfully, the problem was remedied in a few weeks by the contractor, but only if I reached out to the president of the firm.

Q. Has everything met expectations?

Pretty much. The solar panels have substantially reduced my net usage from the grid, as shown in the charts below. I have data from PG&E’s website on my usage going back to 2008. It does not have the ability to show solar production but shows imports and exports and net usage. Production data is only available on the SolarEdge website.

From 2008 to 2015, my monthly consumption averaged 1041 kWh. In 2015, two of my PG&E monthly bills (for electric and gas) exceeded $500. In February 2016, I did a whole house energy upgrade which lowered my consumption to 806 kWh, but that did little to lower my bills since electric rates kept on rising. So, at the end of 2019, I installed solar and storage and my consumption since then has averaged 103 kWh (which includes the charging of my EV).

Electricity consumption varies across the months, since I live in the East Bay Area. Summers are hot and winters are cold. However, what stands out in the figure below is the dramatic difference in the pre-solar and post-solar pattern of usage.

Of course, there is year-to-year variation in the usage pattern, driven largely by weather. That’s brought out in this figure.

Here’s another way to unpack the data.

Q. Can you compare solar production with household consumption?

SolarEdge, through its inverter, knows how much electricity is being produced by the solar panels. It also knows how much electricity is being exported and imported and thus my net usage. Thus, it can solve for my gross consumption using a simple equation: Net usage = Production – Consumption.

The following figures provide consumption and production data by month for the years 2020-2024.  Consumption has risen over the years mostly because I have begun charging mostly at home and because I did not drive the car much during 2020-21 because of the lock down. Production has risen over the years because some foliage that was casting a shadow on the solar panels was removed.

The monthly variation is driven almost entirely due to seasonal variation in the weather – temperatures as well as the number of daylight hours. It’s worth noting that I don’t have a heat pump for HVAC or water heating. I have installed a highly efficient gas furnace and a very low NoX gas water heater.

2020

2021

2022

2023

Q. How much have your bills changed?

Before installing solar, my bills were averaging $200 a month, and rising with every passing year. Since then, the bills have averaged $50 a month. Last year the number was $65 a month.

During this time period, the off-peak rate has doubled, from 17 cents/kWh to 35 cents/kWh. The average rate now is around 46 cents/kWh. PG&E has lowered rates by 10% during the summer to give customers some respite but rates are expected to rise again in the fall. They may hit 50 cents/kWh by year end.

My gross electricity consumption last year was 12,700 kWh using information on the SolarEdge website. Using a price of 40 cents/kWh as the average, which might be an understatement, my monthly bill would come out to $423 a month, as opposed to $65 a month which I paid. That’s a reduction of nearly 85%.

Q. Are you eligible for participating in a VPP?

Early on, SolarEdge in conjunction with PG&E made a VPP offer to me. My system includes an SolarEdge inverter. I gave it some thought but declined the offer. I was concerned they may deplete my battery on critical system days, which would be really hot days. My battery would not have backup power to supply the house if an outage occurred. I continue to have that reservation about the VPP model.

Q. Do you see home storage as a viable way to help Californians control their rising electricity costs?

Yes, but only if storage is paired with solar panels. The battery by itself cannot lower the electric bill.

Q. Do you expect most Californians to include energy storage in their solar projects going forward?

Given the shift from NEM 2.0 to NEM 3.0, a battery would appear to be a must. My understanding is that half of new solar installations now feature batteries. However, since NEM 3.0 has lengthened the payback period considerably, overall solar installations seems to have dropped by 60-80 percent.

Q. Do you see a possibility that NEM 3.0 will be adjusted or repealed, or is it here to stay?

That’s a very difficult question to answer. It all depends on what the legislature wants to do. The CPUC won’t change NEM 3.0 unless it is forced by the legislature to do so.

Dr. Faruqui is an Economist-at-Large who has been working on energy issues since the summer of 1976, when he interned at the California Energy Commission. From 1978 to June 1979, he was a full-time analyst at the CEC. Subsequently, he worked at the Electric Power Research Institute for 11 years and then at several consulting firms, most notably Barakat & Chamblerlin, Charles River Associates, and The Brattle Group.

From pv magazine Global

FOB China prices for wafers have remained stable across the board this week. Mono PERC M10 and n-type M10 wafer prices held steady at $0.141/pc and $0.139/pc, respectively. Likewise, Mono PERC G12 and nN-type G12 wafer prices remained unchanged at $0.209/pc and 0.205/pc, respectively, compared to the previous week.

Although there have been reports that n-type M10 wafer prices might increase due to the switch in China’s domestic wafer production lines from full square wafers sized 182 mm x 182mm to rectangular wafers sized 182 mm x 183.75mm and 182 mm x 210mm, actual transaction prices have remained unchanged except for a few companies’ increased offers.

“Given the sluggish downstream demand and the losses suffered by downstream companies, it is impossible to expect them to accept rises in upstream material costs,” a market source stated.

In contrast, the prices of n-type 210mm wafer set, including the full square 210 mm x 210mm wafers and rectangular 182 mm x 210mm wafers, have softened twice in the past month, according to the OPIS data. Industry insiders attribute this to a shift in production capacity from the 182mm set to the 210mm set, leading to increased inventory of the latter.

“As the market share of a size grows, its inventory rises and prices decrease, which the 210mm wafer set is currently experiencing,” a market observer commented.

According to the OPIS market survey, the majority of wafer operating rates in China’s domestic market are at 50% or lower, with the exception of a Tier-1 wafer producer and one big specialized wafer producer who maintains operating rates of more than 90%.

“Some integrated manufacturers who have halted in-house wafer production due to low market prices, are now sourcing most of their wafers from these two producers,” said a market participant.

A leading Chinese wafer manufacturer announced last week that it will establish a 20 GW ingot and wafering capacity in Saudi Arabia. According to an insider, it is expected the construction to begin this year, with completion and operation slated for 2026.

High gross margins from U.S. module prices are currently the only significant source of potential profitability for supply chain manufacturers, according to a market veteran, noting that this wafer project is expected to target the U.S. market in the future, potentially sourcing polysilicon from the three existing global polysilicon suppliers, the Oman and the UAE polysilicon plants yet to produce, and traceability-compliant Chinese regions.

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.

Heliene, a solar panel provider serving North America, and Premier Energies, a solar cell manufacturer based in India, announced a joint venture to produce solar cells in the United States.

The solar cell manufacturing facility is expected to produce an annual aggregate capacity of 1 GW of N-Type cells to supply Heliene and Premier’s solar cell requirements.

Heliene currently sources solar cells from Premier’s Hyderabad facility for use in module manufacturing at its Mountain Iron, MN location.

“Premier Energies has been a valued partner of Heliene’s for many years now and we share a commitment to providing the highest-quality, most-reliable products to solar customers. With demand for U.S.-made modules and components growing, now is the perfect time to embark on the next phase of our partnership with this joint venture,” said Martin Pochtaruk, CEO of Heliene.

Under the joint venture, Heliene will contribute construction, project management, human resources, financial resource and management, facility operations, supply chain and logistics, and regulatory expertise. Premier will contribute cell technology engineering and operational expertise in the manufacturing process of the cells, manufacturing equipment selection, financial resources, raw material vendor relationships and supply agreements management.

The Inflation Reduction Act of 2022 has tax credits and incentives designed to encourage clean energy manufacturing in the United States. Many large companies have announced solar module manufacturing facilities, but earlier stages in the supply chain like raw polysilicon, ingots, wafers, and solar cell manufacturing facilities have lagged, creating gaps in the domestic supply chain. The Heliene/Premier partnership brings critical solar cell manufacturing capacity to U.S. shores.

In Parts 1 and 2 of this series, pv magazine reviewed the productive lifespan of residential solar panels and inverters. Here, we examine home batteries, how well they perform over time, and how long they last.

Residential energy storage has become an increasingly popular feature of home solar. A recent SunPower survey of more than 1,500 households found that about 40% of Americans worry about power outages on a regular basis. Of the survey respondents actively considering solar for their homes, 70% said they planned to include a battery energy storage system.

Besides providing backup power during outages, many batteries are integrated with technology that allows for intelligent scheduling of the import and export of energy. The goal is to maximize the value of the home’s solar system. And, some batteries are optimized to integrate an electric vehicle charger.

The report noted a steep uptick to consumers showing interest in storage in order to self-supply solar generation, suggesting that lowered net metering rates are discouraging export of local, clean electricity. Nearly 40% of consumers reported self-supply as a reason for getting a storage quote, up from less than 20% in 2022. Backup power for outages and savings on utility rates were also listed as top reasons for including energy storage in a quote.

Attachment rates of batteries in residential solar projects have climbed steadily  in 2020 8.1% of residential solar systems attached batteries, according to Lawrence Berkeley National Laboratory, and in 2022 that rate climbed over 17%.

Life of a battery

Warranty periods can offer a look in installer and manufacturer expectations of the life of a battery. Common warranty periods are typically around 10 years. The warranty for the Enphase IQ Battery, for instance, ends at 10 years or 7,300 cycles, whatever occurs first.

Solar installer Sunrun said batteries can last anywhere between 5-15 years. That means a replacement likely will be needed during the 20-30 year life of a solar system.

Battery life expectancy is mostly driven by usage cycles. As demonstrated by the LG and Tesla product warranties, thresholds of 60% or 70% capacity are warranted through a certain number of charge cycles.

Two use-scenarios drive this degradation: over charge and trickle charge, said the Faraday Institute. Overcharge is the act of pushing current into a battery that is fully charged. Doing this can cause it to overheat, or even potentially catch fire.

Trickle charge involves a process in which the battery is continually charged up to 100%, and inevitably losses take place. The bounce between 100% and just under 100% can elevate internal temperatures, diminishing capacity and lifetime.

Another cause of degradation over time is the loss of mobile lithium-ions in the battery, said Faraday. Side reactions in the battery can trap free usable lithium, thereby lowering capacity gradually.

While cold temperatures can halt a lithium-ion battery from performing, they do not actually degrade the battery or shorten its effective life. Overall battery lifetime is, however, diminished at high temperatures, said Faraday. This is because the electrolyte that sits between the electrodes breaks down at elevated temperatures, causing the battery to lose its capacity for Li-ion shuttling. This can reduce the number of Li-ions the electrode can accept into its structure, depleting the lithium-ion battery capacity.

Maintenance

It is recommended by the National Renewable Energy Laboratory (NREL) to install a battery in a cool, dry place, preferably a garage, where the impact of a fire (a small, but non-zero threat) may be minimized. Batteries and components around them should have proper spacing to allow cooling, and regular maintenance check-ups can be helpful in ensuring optimal operation.

NREL said that whenever possible, avoid repeated deep discharging of batteries, as the more it is discharged, the shorter the lifetime. If the home battery is discharged deeply every day, it may be time to increase the battery bank’s size.

Batteries in series should be kept at the same charge, said NREL. Though the entire battery bank may display an overall charge of 24 volts, there can be varied voltage among the batteries, which is less beneficial to protecting the entire system over the long run. Additionally, NREL recommended that the correct voltage set points are set for chargers and charge controllers, as determined by the manufacturer.

Inspections should occur frequently, too, said NREL. Some things to look for include leakage (buildup on the outside of the battery), appropriate fluid levels, and equal voltage. NREL said each battery manufacturer may have additional recommendations, so checking maintenance and data sheets on a battery is a best practice.

From pv magazine Global

Researchers at the Universiti Teknikal Malaysia Melaka have outlined a techno-economic optimization approach to define the appropriate power sizing ratio (PSR) for inverters used in grid-connected PV systems.

The PSR is the ratio of the inverter’s rated power to the total rated power of the connected PV modules and is crucial to maximizing energy yield and income. “An undersized inverter limits the system’s ability to convert all the generated DC power to AC power, leading to potential energy losses,” the scientists explained. “Conversely, an oversized inverter incurs higher initial costs without a proportional increase in energy production.”

The proposed methodology uses a pattern search algorithm (PSA), which is an optimization technique commonly utilized for problems with complex relationships and potentially noisy data, to ensure an accurate representation of real-world inverter behavior.

The model considers radiation, convection thermal representations, and real-world weather data. It also takes into account data from the inverters’ datasheets to evaluate the efficiency curve of the devices. From this curve, it then extracts key points to identify efficiency values between the chosen data points.

“The model undergoes a calibration phase where the efficiency curve points are iteratively adjusted by the PSA until the estimated/modeled values closely match the actual measurements obtained from the real system over a predefined period,” the group explained. “This calibration step guarantees that the model accurately reflects the real-world performance of the system.”

According to the scientists, the model can estimate the annual power yield of a solar array for each iteration step through various DC/AC power ratios, which in turn allows PV system owners to find the optimized ratio that maximizes energy production.

They also warned that the proper selection of the optimal PSR needs to be complemented by economic considerations relating to inverter costs, operation and maintenance, inverter complexity, and monitoring systems. “It’s important to note that the cost function doesn’t directly represent monetary value but rather a relative measure of economic performance,” they stressed. “The actual economic feasibility would depend on specific system costs and electricity prices.”

The novel methodology was presented in the study “Techno-economic optimization of photovoltaic (PV)-inverter power sizing ratio for grid-connected PV systems,” published in Results in Engineering.

“Future research directions involve exploring the integration of additional factors into the model,” the research team concluded. “These factors could include advanced weather forecasting capabilities, dynamic pricing schemes, and potential application to different types of PV systems or even broader renewable energy systems.”

In the first part of this series, pv magazine reviewed the productive lifespan of solar panels, which are quite resilient. In this part, we examine residential solar inverters in their various forms, how long they last, and how resilient they are.

The inverter, a device that converts the DC power produced by solar panels into usable AC power, can come in a few different configurations. 

The two main types of inverters in residential applications are string inverters and microinverters. In some applications, string inverters are equipped with module-level power electronics (MLPE) called DC optimizers. Microinverters and DC optimizers are generally used for roofs with shading conditions or sub-optimal orientation (not south-facing).

In applications where the roof has a preferable azimuth (orientation to the sun) and little no shading issues, a string inverter can be a good solution.

String inverters generally come with simplified wiring and a centralized location for easier repairs by solar technicians. Typically they are less expensive, said Solar Reviews. Inverters can typically cost 10-20% of the total solar panel installation, so choosing the right one is important.

How long do they last? 

While solar panels can last 25 to 30 years or more, inverters generally have a shorter life, due to more rapidly aging components. A common source of failure in inverters is the electro-mechanical wear on the capacitor in the inverter. The electrolyte capacitors have a shorter lifetime and age faster than dry components, said Solar Harmonics.

EnergySage said that a typical centralized residential string inverter will last about 10-15 years, and thus will need to be replaced at some point during the panels’ life.

String inverters generally have standard warranties ranging from 5-10 years, many with the option to extend to 20 years. Some solar contracts include free maintenance and monitoring through the term of the contract, so it is wise to evaluate this when selecting inverters.

Microinverters have a longer life, EnergySage said they can often last 25 years, nearly as long as their panel counterparts. Roth Capital Partners said its industry contacts generally report microinverter failures at a substantially lower rate than string inverters, though the upfront cost is generally a bit higher in microinverters.

Microinverters typically have a 20 to 25-year standard warranty included. It should be noted that while microinverters have a long warranty, they are still a relatively new technology from the past ten years or so, and it remains to be seen if the equipment will fulfill its 20+ year promise.

The same goes for DC optimizers, which are typically paired with a centralized string inverter. These components are designed to last for 20-25 years and have a warranty to match that time period.

As for inverter providers, a few brands hold dominant market share. In the United States, Enphase the market leader for microinverters, while SolarEdge leads in string inverters. Tesla has been making waves in the residential string inverter space, taking up market share, though it remains to be seen how much of an impact Tesla’s market entry will make, said an industry note from Roth Capital Partners.

(Read: “U.S. solar installers list Qcells, Enphase as top brands“)

Failures 

A study by kWh Analytics found that 80% of solar array failures occur at the inverter level. There are numerous causes of this.

According to Fallon Solutions, one cause is grid faults. High or low voltage due to grid fault can cause the inverter to stop working, and circuit breakers or fuses can be activated to protect the inverter from high-voltage failure.

Sometimes failure can occur at the MLPE level, where the components of power optimizers are exposed to higher temperatures on the roof. If reduced production is being experienced, it could be a fault in the MLPE.

Installation must be done properly as well. As a rule of thumb, Fallon recommended that the solar panel capacity should be up to 133% of the inverter capacity. If the panels are not properly matched to a right-size inverter, they will not perform efficiently.

Maintenance

To keep an inverter running more efficiently for a longer period, it is recommended to install the device in a cool, dry place with lots of circulating fresh air. Installers should avoid areas with direct sunlight, though specific brands of outdoor inverters are designed to withstand more sunlight than others. And, in multi-inverter installations, it is important to be sure there is proper clearance between each inverter, so that there isn’t heat transfer between inverters.

It is a best practice to inspect the outside of the inverter (if it is accessible) quarterly, making sure there are no physical signs of damage, and all vents and cooling fins are free from dirt and dust.

It is also recommended to schedule an inspection through a licensed solar installer every five years. Inspections typically cost $200-$300, though some solar contracts have free maintenance and monitoring for 20-25 years. During the checkup, the inspector should check inside the inverter for signs of corrosion, damage, or pests.

In the next installment of the series, pv magazine will examine the life of residential battery energy storage applications.

U.S. Senators Joe Manchin (I-WV) and John Barrasso (R-WY), chair and ranking member of the Senate Energy and Natural Resources Committee, released the Energy Permitting Reform Act of 2024. Find the full bill text here.

The Act is designed to shorten timelines, before, during, and after litigation on federal authorizations for energy and mineral projects.

Manchin called the legislation “a commonsense, bipartisan piece of legislation that will speed up permitting and provide more certainty for all types of energy and mineral projects without bypassing important protections for our environment and impacted communities.”

The bill establishes 150-day statute of limitations from the date of the final agency action on a project; requires courts to expedite review of legal challenges; and sets a 180-day deadline for federal agencies to act on remanded authorizations.

The bill sets deadlines and doubles production targets for renewable energy permitting on federal lands. It also streamlines environmental reviews for low-disturbance renewable, electric grid, and storage projects. It also makes several changes to accelerate the permitting processes for fossil fuels projects.

The act also reforms existing backstop siting authority for interstate electric transmission lines sets requirements for interregional transmission planning. The provisions are designed to provide two pathways for transmission development that include clear standards for cost allocation among customers that benefit from a project. The legislation creates an interregional planning requirement that ensures regions jointly address needs and a process that allows individual applicants to propose national-interest projects.

Find a section-by-section breakdown of the legislation here.

“We have the technology, workforce, and financial capital to build great things, but we lack a governing process that is designed to succeed. This legislation changes that,” said Jason Grumet, chief executive officer, American Clean Power.

The Solar Energy Industries Association (SEIA) welcomed the legislation.

“For years, SEIA has been calling for a fundamental shift in the way we build transmission capacity and has long advocated for reforms that fairly allocate costs. While we’re still reviewing the details, this is a conversation worth having,” said Abigail Ross Hopper, president and chief executive officer, SEIA.

The Center for Biological Diversity warned that too many important environmental review processes are stripped in the legislation, particularly for the development of new fossil fuels infrastructure. In a letter to Senate majority leader Chuck Schumer, the Center warned:

“Weakening our bedrock environmental protection laws doesn’t help renewable energy. It only serves to enrich the fossil fuel industry,” said Camden Weber, climate and energy policy specialist at the Center for Biological Diversity. “Permitting reform is one of the most insidious euphemisms on Capitol Hill.”

A national study from the University of Texas found that from 2010 to 2021, less than 5% of solar and wind projects required a comprehensive environmental bill under the National Environmental Protection Act (NEPA).

The utility-scale solar energy sector is rapidly evolving, with many innovations aimed at reducing costs and increasing efficiency. One such innovation is fully integrated switchgear skids – which consist of transformers plus switchboards and SCADA – produced in a factory setting as opposed to integrating these components in the field.

By integrating these components in a factory setting, you can streamline installation processes and save tens of thousands of dollars. This is made possible by reducing costly field labor, conduit and wire, including through the skidded switchboard, in which the MVT is direct bussed. This is accomplished all while delivering the highest quality installation on projects. Castillo Engineering, Recon Corporation, EPEC & ReBoSS are achieving these benefits today by designing and building fully integrated transformer (XFMR) / switchboard (SWBD) skids in a factory rather than at solar sites.

Understanding Switchboards in Solar Projects

Low voltage switchboards are a crucial component in electrical systems, consisting of the busbar, circuit breakers, and protective relays that control, protect, and isolate electrical equipment. In solar projects, switchboards play a vital role collecting the power from inverters, and tying that power into the electrical grid. By integrating switchboards into the design phase & building them into skids in a factory before arriving on-site, you can significantly reduce costs, expedite project timelines, and improve your solar energy system’s overall performance and reliability. Avoiding over-specification in fault current ratings is critical.

Benefits of Integrating Switchboards into Solar Designs

1. Shortest Lead Times

Integrating the XFMR, SWBD, and SCADA in a factory setting is not subject to weather and other supply chain issues that often plague completing this integration at a solar construction site. For this reason, EPEC, ReBoSS and Castillo Engineering ensure the shortest construction build times in the industry for developers and EPCs like Recon Corporation. Also, this reduction in construction time due to lack of weather and labor delays means the developer can cease their construction loans faster, which increases the solar project’s profitability.

2. Highest Quality Installations

ReBoSS and EPEC are highly competent in designing & delivering fully integrated XFMR/SWBD skids custom-designed to power renewable energy projects. Over the years, EPEC has built a specialized team that ensures that the highest quality XFMR/SWBD skids can arrive on time and with superior quality assurance and quality control. Unlike when switchgear, transformer, and other components are integrated on the pads in the field, completing this integration in a controlled environment, factory setting with a highly trained team dramatically increases the quality control and it lessens the time required to complete the switchgear integration.

3. Reduced Installation & Equipment Costs

Integrating switchgear onto skids within a factory setting versus in the field yields significant cost savings. Pre-integrated systems reduce labor costs because labor hours spent in a factory to install switchgear are less than the time spent integrating the same equipment in the field. EPEC, ReBoSS and Castillo Engineering customers have reported saving between $9,000 to $20,000 per transformer/switchboard connection when using a direct bus versus the typical cable connection.

With the direct bus and skid connection, there is a significant reduction in cost because there is less conduit, wire, and labor to procure compared to the direct bus connection alternative. Close-coupling the XFMR & SWBD and integrating it on a skid significantly reduces the scope of work and time required for the highly specialized medium voltage labor to complete this switchgear integration in the field. This avoids unnecessary, extremely labor-intensive elements that would otherwise elongate schedules from weather delays, including excavation, pad forming, conduit installation, equipment setting, cable pulling, an excessive amount of high ampacity cable terminations, and equipment grounding conductor runs.

4. Maximum Tax Savings

The new Inflation Reduction Act (IRA) law allows for “manufactured” equipment with domestic content to be counted as part of the percentage required to qualify for the additional 10% “domestic content” incentive. Equipment that is built on a solar site is not considered “manufactured equipment” and therefore cannot be counted toward the domestic content percentage, which is presently at 45 percent for 2025. Integrating the switchboards onto a skid in a factory setting meets this manufactured equipment definition. As a result, solar developers can add this equipment to their tally and possibly leverage the additional IRA 10 percent tax incentives to maximize the project’s financial returns.

5. Simplified Maintenance

A well-integrated switchboard system simplifies maintenance and troubleshooting. A comprehensive design that includes switchboards from the outset makes it easier to identify and address issues, reducing downtime and maintenance costs. This ensures that the solar plant operates smoothly with minimal interruptions. An above-grade bus throat will have fewer issues than below-grade circuits over the life of the farm.  Even if there is an issue down the road, it is much simpler to troubleshoot/repair.

Residential solar panels are often sold with long-term loans or leases, with homeowners entering contracts of 20 years or more. But how long do panels last, and how resilient are they?

Panel life depends on several factors, including climate, module type, and the racking system used, among others. While there isn’t a specific “end date” for a panel per se, loss of production over time often forces equipment retirements.

When deciding whether to keep your panel running 20-30 years in the future, or to look for an upgrade at that time, monitoring output levels is the best way to make an informed decision.

Degradation

The loss of output over time, called degradation, typically lands at about 0.5% each year, according to the National Renewable Energy Laboratory (NREL).

Manufacturers typically consider 25 to 30 years a point at which enough degradation has occurred where it may be time to consider replacing a panel. The industry standard for manufacturing warranties is 25 years on a solar module, said NREL.

Given the 0.5% benchmark annual degradation rate, a 20-year-old panel is capable of producing about 90% of its original capability.

Panel quality can make some impact on degradation rates. NREL reports premium manufacturers like Panasonic and LG have rates of about 0.3% per year, while some brands degrade at rates as high as 0.80%. After 25 years, these premium panels could still produce 93% of their original output, and the higher-degradation example could produce 82.5%.

(Read: “Researchers assess degradation in PV systems older than 15 years“)

A sizeable portion of degradation is attributed to a phenomenon called potential induced degradation (PID), an issue experienced by some, but not all, panels. PID occurs when the panel’s voltage potential and leakage current drive ion mobility within the module between the semiconductor material and other elements of the module, like the glass, mount, or frame. This causes the module’s power output capacity to decline, in some cases significantly.

Some manufacturers build their panels with PID-resistant materials in their glass, encapsulation, and diffusion barriers.

All panels also suffer something called light induced degradation (LID), in which panels lose efficiency within the first hours of being exposed to the sun. LID varies from panel to panel based on the quality of the crystalline silicon wafers, but usually results in a one-time, 1-3% loss in efficiency, said testing laboratory PVEL, PV Evolution Labs.

Weathering

The exposure to weather conditions is the main driver in panel degradation. Heat is a key factor in both real-time panel performance and degradation over time. Ambient heat negatively affects the performance and efficiency of electrical components, according to NREL.

By checking the manufacturer’s data sheet, a panel’s temperature coefficient can be found, which will demonstrate the panel’s ability to perform in higher temperatures.

The coefficient explains how much real-time efficiency is lost by each degree of Celsius increased above the standard temperature of 25 degrees Celsius. For example, a temperature coefficient of -0.353% means that for every degree Celsius above 25, 0.353% of total production capability is lost.

Heat exchange drives panel degradation through a process called thermal cycling. When it is warm, materials expand, and when the temperature lowers, they contract. This movement slowly causes microcracks to form in the panel over time, lowering output.

In its annual Module Score Card study, PVEL analyzed 36 operational solar projects in India, and found significant impacts from heat degradation. The average annual degradation of the projects landed at 1.47%, but arrays located in colder, mountainous regions degraded at nearly half that rate, at 0.7%.

Proper installation can help deal with heat related issues. Panels should be installed a few inches above the roof, so that convective air can flow beneath and cool the equipment. Light-colored materials can be used in panel construction to limit heat absorption. And components like inverters and combiners, whose performance is particularly sensitive to heat, should be located in shaded areas, suggested CED Greentech.

Wind is another weather condition that can cause some harm to solar panels. Strong wind can cause flexing of the panels, called dynamic mechanical load. This also causes microcracks in the panels, lowering output. Some racking solutions are optimized for high-wind areas, protecting the panels from strong uplift forces and limiting microcracking. Typically, the manufacturer’s datasheet will provide information on the max winds the panel is able to withstand.

The same goes for snow, which can cover panels during heavier storms, limiting output. Snow can also cause a dynamic mechanical load, degrading the panels. Typically, snow will slide off of panels, as they are slick and run warm, but in some cases a homeowner may decide to clear the snow off the panels. This must be done carefully, as scratching the glass surface of the panel would make a negative impact on output.

(Read: “Tips for keeping your rooftop solar system humming over the long term“)

Degradation is a normal, unavoidable part of a panel’s life. Proper installation, careful snow clearing, and careful panel cleaning can help with output, but ultimately, a solar panel is a technology with no moving parts, requiring very little maintenance.

Standards

To ensure a given panel is likely to live a long life and operate as planned, it must undergo standards testing for certification. Panels are subject to the International Electrotechnical Commission (IEC) testing, which apply to both mono- and polycrystalline panels.

EnergySage said panels that achieve IEC 61215 standard are tested for electrical characteristics like wet leakage currents, and insulation resistance. They under go a mechanical load test for both wind and snow, and climate tests that check for weaknesses to hot spots, UV exposure, humidity-freeze, damp heat, hail impact, and other outdoor exposure.

IEC 61215 also determines a panel’s performance metrics at standard test conditions, including temperature coefficient, open-circuit voltage, and maximum power output.

Also commonly seen on a panel spec sheet is the seal of Underwriters Laboratories (UL), which also provides standards and testing. UL runs climactic and aging tests, as well as the full gamut of safety tests.

Failures

Solar panel failure happens at a low rate. NREL conducted a study of over 50,000 systems installed in the United States and 4,500 globally between the years of 2000 and 2015. The study found a median failure rate of 5 panels out of 10,000 annually.

Panel failure has improved markedly over time, as it was found that system installed between 1980 and 2000 demonstrated a failure rate double the post-2000 group.

(Read: “Top solar panel brands in performance, reliability and quality“)

System downtime is rarely attributed to panel failure. In fact, a study by kWh Analytics found that 80% of all solar plant downtime is a result of failing inverters, the device that converts the panel’s DC current to usable AC. pv magazine will analyze inverter performance in the next installment of this series.

The Massachusetts House of Representatives has passed H.4876, a bill to address solar and energy storage development challenges in the state. The bill will next go to the state Senate to finalize a compromise bill.

The bill includes provisions to incentivize solar and storage development, streamline siting and permitting processes at both the state and local levels, and address grid interconnection challenges.

“House Bill 4876 will accelerate the build-out of solar and energy storage technology and address permitting and interconnection red tape that has been holding the Massachusetts solar and storage market back,” said Valessa Souter-Kline, northeast regional director, Solar Energy Industries Association (SEIA).

The reforms include time limits for authorities having jurisdiction (AHJ) to authorize permits. It also creates a pathway for a streamlined permit appeal process.

The bill also creates a statewide procurement of 5 GWh of energy storage.

“Massachusetts’s solar and storage industry has been surpassed by its regional neighbors in recent years, but these reforms are the spark the market needs to reach the Commonwealth’s bold clean energy vision,” said Souter-Kline.

Find the full bill text here.

Residential solar company SunPower (Nasdaq: SPWR) suffered a 70% decline in share prices of its stock this week, crashing nearly 50% on Friday, July 19.

Reuters reported that SunPower communicated to its employees that it will pause several core operations. The company announced it will deactivate its lease and power purchase agreement offerings and will discontinue new product shipments.

SunPower said it will stop countersigning new agreements and is unable to support installation services for shipments currently in transit or already delivered.

Residential solar in the United States has been struggling over the past two years as rising interest rates and regulatory changes have squeezed the value offered to customers. As demand fell, rising excess inventory posed further challenges for installers. Installations are down 20% nationwide in 2024.

SunPower’s struggles have continued through persistent high interest rates. In December 2023 the company defaulted on its debt and issued a warning that it had “going concerns” about remaining in business.

In April the company announced it would close numerous installation service centers across the country and cut about 26% of its workforce.

The company’s share price target was cut to $0 by Gordon Johnson from GLJ Research. Roth Capital Partners said competitors Sunrun and Sunnova are likely to gain from the lost market share left behind by SunPower.

“We think this effectively marks the end for SPWR as an operating business,” said an analyst note from Guggenheim. “Considering the debt that the company has accumulated, we believe that SPWR’s equity no longer has any value.”

Prices in the module market were assessed stable-to-soft for the second consecutive week. The Chinese Module Marker (CMM), the OPIS benchmark assessment for TOPCon modules from China was assessed at $0.096/W, down $0.002/W reflecting discussions heard while Mono PERC module prices were assessed stable at $0.090/W from the previous week.

The TOPCon market was rather “chaotic” in the week to Tuesday with prices heard in a wide range. Some Tier 1 module manufacturers continued to offer cargoes at $0.100/W FOB China while lower offers from Tier 2 and Tier 3 module sellers had emerged at $0.085/W FOB China. These low prices were “distorting” the market and creating a false impression that mainstream TOPCon prices had rapidly fallen so low in a short period of time, a market source said.

Market participants OPIS surveyed expected further declines in TOPCon prices in the coming weeks as module makers compete to secure new orders and clear inventories. Although module makers are already burning cash and there is a limit to how much lower prices can fall, Tier 1 players are in a better cash flow situation compared to the smaller players in the market. However, several big players have already announced losses in the first half of the year and if this vicious cycle of non-stop price war continues, the industry will start to see a market consolidation very soon, an industry source said.

Business has slowed considerably with buyers enquiring for smaller volume of cargoes compared to before and sales performance this quarter has been dismal, a module seller said. Sales projections for the third quarter were equally bearish as module prices were expected to fall further with no market recovery in sight, the seller added.

The spread between TOPCon and Mono PERC prices has started to narrow. It is not surprising for Mono PERC prices to be slightly lower or similar to TOPCon prices as module makers are selling based on their Mono PERC inventory levels, a market source said. OPIS heard majority of discussions of Mono PERC at $0.090/W FOB China though a few sellers kept offers at $0.093-0.095/W FOB China.

In the Chinese market, the Ministry of Industry and Information Technology (MIIT) published proposals seeking public opinions on the “Regulatory Conditions for Photovoltaic Manufacturing Industry (2024 Edition)” and “Administrative Measures for Announcement of Photovoltaic Manufacturing Industry (2024 Edition)” on July 9.

One of the proposals was to raise the minimum capital ratio for new construction and expansion of photovoltaic manufacturing projects to 30% from 20% previously for wafer, cell and module production. Amongst the other proposals, MIIT guides photovoltaic enterprises to reduce photovoltaic manufacturing projects that simply expand production capacity.

One market veteran OPIS spoke to expressed skepticism that such measures would curtail production expansions and restore supply and demand balance in the Chinese market as capacity expansion plans are announced almost every day. Any positive impact from these measures would take at least two to three quarters from the implementation date for any improvements to be seen, the veteran added.

OPIS assessed the forward pricing curve for U.S. delivered duty-paid (DDP) mono PERC modules lower this week, indicating softer market values. Prices for PERC modules slated for Q4 delivery averaged $0.291/W ranging from $0.240-0.365/W on a DDP U.S. basis, while prices for 2025 delivery averaged $0.315-0.319/W ranging between $0.270/W and $0.365/W DDP U.S.

A producer noted that demand has weakened due to uncertainties surrounding U.S. tariff policies, while more competitively priced cargoes are emerging from Southeast Asian countries like Indonesia and Laos. The potential tariffs are expected to impact delivery schedules, and freight volatility remains a concern for buyers. Trade sources shared that TOPCon modules for spot loading from Indonesia and Laos are at $0.24/W to $0.28/W on a DDP U.S. basis.

In response to potential tariff complications, there has been an increase in Indian module shipments to the U.S., as buyers are cautious about purchasing from Southeast Asia. According to an industry source, May module shipments from India to the U.S. reached approximately 1 GW, accounting for around 20% of U.S. module imports. The source noted that India had previously represented a smaller share of U.S. module imports before May. Additionally, the source reported a 10-15% decline in Southeast Asian module imports in May compared to March and April.

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 Energy Information Administration reported in its monthly electric power industry report that battery adoption rates are rising among solar customers in California.

In October 2023, about 20% of California solar shoppers opted to include a battery energy storage system in their installation. In April 2024, that number has climbed to over 50%.

The change to battery-included systems is largely due to the transition to Net Energy Metering 3.0, a regulatory structure that decreased the amount paid to customers for sending solar production directly to the grid. Due to an hourly mismatch of peak solar production and peak electricity demand, regulators shifted compensation rates to place an emphasis on storing and dispatching solar generated electricity when it is needed the most.

A 50% or greater battery attachment rate is a significant change for the state’s solar industry. Solar-plus-battery systems make up about 9% of all installed residential net metering capacity in California. Over 40,000 new systems were added between October 2023 and April 2024, accounting for 232 MW of new battery storage capacity in the state, said EIA.

While NEM 3.0 achieved its intended effect of encouraging more battery installations, the rulemaking decision was unpopular with solar advocates. The change increased the overall sticker price for installing solar, and while you get the added benefit of battery backup during outages, the amount of time it will take to breakeven on a solar investment in California has increased. This has led to a decline in installations, with Q1 2024 having the lowest installed capacity in a quarter since 2021 with a little over 300 MW of solar installed.

California now has more than 12,000 MW of installed solar capacity in residential net metering systems smaller than 1 MW. Residential installations account for more than 70% of installed net metering capacity, and about one-third of total installed solar capacity in the state.

“Our data show that during the third quarter of 2023, 83,376 new residential net metering photovoltaic systems were installed, compared with 70,152 systems connected under the old NEM 2.0 rule during the same period in 2022. However, we cannot differentiate the systems that requested to be grandfathered to NEM 2.0,” said EIA.

The first quarter of 2024 saw an additional 46,631 systems installed. Since January 2022, an average of 21,000 solar systems were added every month.