Higher Power PV Modules Drive Up BOS Costs

SK Signet (KONEX: 260870), a global manufacturer of high-power EV charging solutions based in South Korea, announced on April 2nd that the Mayor of Plano, Texas, and an official delegation visited its headquarters and the R&D center.

The visit was attended by John Muns, Mayor of Plano, Texas, and Mark Israelson, City Manager, along with other key city officials. During the visit, they directly observed SK Signet's R&D capabilities and ultra-fast charging technologies. The delegation toured advanced testing facilities, including the design and validation processes for ultra-fast chargers, a large-scale EMC chamber, and vehicle simulators, gaining insight into the company's technological development and quality assurance systems.

During the visit, both parties discussed future collaboration, focusing on expanding EV charging infrastructure across Plano and the broader North American region, as well as strengthening SK Signet's local manufacturing capabilities. Discussions also covered potential public-private partnerships and the expansion of EV charging networks in line with U.S. federal and Texas state clean mobility initiatives.

SK Signet established its production base in Plano, Texas in 2023, marking a significant step in accelerating its North American market expansion. The company has since supplied more than 3,000 ultra-fast chargers across the U.S. market, positioning itself as a leading player in the global EV charging infrastructure industry. The Plano facility serves as a strategic hub, enabling rapid response to local demand while ensuring supply chain stability and scalability through localized production.

Plano is widely recognized as a key business hub in North America, offering a business-friendly regulatory environment, a strong talent pool, and a strategic location. Efficient and predictable permitting processes, access to skilled professionals supported by leading universities, and nationwide logistics connectivity provide substantial advantages for SK Signet's continued growth.

Hyung-Ki Cho, CEO of SK Signet, said, "Plano serves as a critical North American hub with a business-friendly environment, strong talent, and strategic positioning, providing a solid foundation for building a stable supply chain and expanding our business. Through close collaboration with Plano, we will continue to contribute to the expansion of EV charging infrastructure in North America while fostering shared growth with the local community and industry ecosystem."

Mayor John Muns added, "It is very meaningful to see SK Signet's advanced research facilities and outstanding technological capabilities firsthand. The company's production base in Plano plays a pivotal role in the local economy and also in advancing EV infrastructure across the United States. We will continue to actively support the company at the city level and work closely with state and federal governments to ensure its continued growth."

Meanwhile, SK Signet recently introduced a new 400kW all-in-one ultra-fast charger, significantly strengthening its product portfolio. Featuring a modular architecture that integrates multiple high-density SiC-based power modules, the charger achieves higher output density and delivers up to 96.5% efficiency, enabling reduced operating costs and stable performance. Compared with installing two existing V2 200kW all-in-one units, the 400kW all-in-one configuration reduces footprint per output by approximately 54%, allowing efficient deployment in space-constrained environments such as shopping centers, gas stations, and urban parking facilities.

In addition, the system incorporates liquid-cooled cables and a swing-arm cable management system to enhance durability and user convenience. It supports both the North American Charging Standard (NACS) and CCS1 connectors, ensuring compatibility across a wide range of EV models.

Alongside these hardware innovations, SK Signet is advancing its operational capabilities with a high uptime rate of 99% and enhanced management systems, accelerating its transition from a manufacturer to a "total solution provider."

SK Signet | sksignet.com

Global energy markets are facing unprecedented volatility. With geopolitical tensions in the Middle East disrupting traditional oil supplies, the mandate is clear: nations must accelerate the transition to domestic, renewable energy. Organizations like the New Lines Institute and the EPA are urging the rapid deployment of solar panels, electric vehicles (EVs), and localized battery storage systems (ESS) to insulate economies from fossil fuel shocks.

But as the demand for EVs and smart grids surges, a hidden risk is emerging on the factory floor.

The rush to manufacture millions of battery units and charging stations is putting immense pressure on global supply chains. According to Leon Huang, CEO of digital manufacturing platform RapidDirect, the industry’s hyper-focus on software and grid integration is causing a dangerous blind spot regarding the physical hardware.

"We are treating battery storage as a software challenge when it is fundamentally a material engineering challenge," Huang explains. "You can have the most advanced smart grid in the world, but if the physical enclosure housing a high-density lithium-ion battery is manufactured with sub-standard polymers to cut costs, you are putting a live fire hazard in someone's garage."

To successfully de-risk the green energy transition, Huang outlines three critical manufacturing shifts the industry must adopt:

1. Shortening the Supply Chain Through Localized Prototyping 

Relying on fragmented, overseas supply chains for critical battery components leaves the industry vulnerable to the very geopolitical disruptions we are trying to escape. By boosting local production and utilizing rapid on-demand manufacturing, companies can shorten their supply chains significantly. "When engineers can rapidly prototype and test battery enclosures locally using CNC machining or industrial 3D printing, they iterate safety features in days, not months," says Huang. "This localized agility is exactly what prevents shipping bottlenecks and ensures material purity is strictly monitored."

2. Mandating Thermal-Defensive Materials 

As EV charging speeds increase and home batteries store more capacity, thermal management becomes the ultimate safety barrier. Huang notes that manufacturers must prioritize high-performance materials over cheaper alternatives. This includes utilizing UL94-V0 rated flame-retardant plastics that self-extinguish within seconds, and precision-machined aluminum alloys that act as functional heat sinks. Efficiently dissipating heat prevents the thermal runaway events that plague poorly constructed units.

3. Precision Engineering for Environmental Resilience 

Energy infrastructure must withstand brutal environmental conditions. "If an EV charger’s housing has even a millimeter of variance in its manufacturing tolerance, thermal cycling will eventually draw moisture into the electronics," Huang warns. Adopting strict Design for Manufacturability (DFM) standards ensures that seals are perfectly airtight, protecting internal components from the moisture and dust that lead to electrical shorts.

Ultimately, government subsidies and energy-saving policies will only succeed if the hardware holds up.

"The transition to localized energy storage is the right move for global stability," Huang concludes. "But we cannot trade energy risk for physical risk. De-risking our future requires us to look incredibly closely at the materials we use. Better engineering makes for a safer transition."

RapidDirect | https://www.rapiddirect.com/

BGE has submitted a new proposal under the 2024 Distributed Renewable Integration and Vehicle Electrification (DRIVE) Act to help modernize Maryland’s electric grid. The plan makes use of technology like home battery storage, electric vehicles (EVs), and other smart devices to strategically support BGE’s distribution grid. By joining the program, customers can earn incentives for allowing BGE to temporarily adjust how these devices use electricity during times of high energy use. This helps keep the grid running smoothly and lowers energy costs. The DRIVE Act proposal is a key part of The Exelon Promise: working for long-term solutions that keep energy affordable for Maryland families and businesses.

BGE’s proposal is in response to the DRIVE Act and includes the next-generation implementation of load management programs for the purpose of reducing electricity use and increasing customer affordability. Energy markets have changed; BGE’s proposal would innovate operations working to reduce capacity by utilizing dispatchable flexible resources. This would reduce strain on the electric grid and help keep energy costs affordable for customers.

In addition to the expanded capabilities offered in BGE’s proposal, the DRIVE Act presents the opportunity to align with BGE’s existing load management programs (currently filed under EmPOWER Maryland) by bringing them into the DRIVE Act. This will allow for more cohesive program implementation, more transparent evaluation and oversight, and a streamlined customer experience.

With supply costs continuing to rise, the DRIVE Act allows utilities to create a virtual power plant (VPP) that connects customer-owned devices, like whole-home battery storage systems and EVs, to help balance the grid during high-demand periods, which ultimately lowers costs on consumers’ bills. VPPs in California and Puerto Rico have shown to maintain system reliability and avoid outages by engaging directly with customers to optimize their usage in a way that benefits grid operations.  

BGE’s primary goal is to help ensure all the communities it serves benefit from these grid modernization efforts. By investing in the future of Maryland’s energy infrastructure, BGE is committed to delivering reliable, affordable, and sustainable energy solutions.

“BGE’s proposed solutions give customers more tools to manage their energy use, save money, and support a cleaner, more resilient grid,” said John Frain, vice president of Regulatory Policy and Strategy at BGE. “Advancing time‑of‑use options, on‑site renewables, and virtual power plant technology can strengthen reliability while expanding customer choice – key priorities for BGE as we support Maryland’s energy future.” 

Benefits for Maryland customers: 

• Lower Peak Energy Costs: The program helps control long-term energy costs by reducing strain on the grid during high-demand periods. 
• Customer Incentives: Incentives will be available for both residential and commercial customers who participate. 
• More Ways to Participate: Customers can enroll with whole-home battery storage systems, EVs, and other flexible energy resources. 

Benefits beyond energy savings: 

• A More Resilient Grid: Up to 188 MW (enough to power about 125,000 homes) of flexible load resources from participating customer devices will be directed to reduce system peaks and, in limited scenarios, even export power from customer batteries and EVs to the distribution grid. Flexible load resources also support grid stability during extreme weather events. 
• Cleaner Energy Future: By participating in BGE’s VPP, customers will be incentivized to reduce usage and provide benefits to the grid, which can help encourage more customers to purchase these devices.

If BGE’s proposal is approved, customers may enroll and earn incentives during the two-year pilot. Results from the pilot will inform future permanent programs and support Maryland’s long‑term goals for reliability, affordability, resilience, and clean energy. A hearing to review BGE’s proposal with the PSC is scheduled for April 7 and 8, 2026. 

BGE | https://www.bge.com/

Newly released security footage from an e-bike facility in Quebec, Canada, shows a lithium-ion battery fire igniting and rapidly escalating—then being immediately extinguished before it could destroy the business or cause further harm. The difference-maker: the facility owner had proactively equipped his operation with eFireX lithium fire extinguishers and applied them, eliminating the threat in under 60 seconds.

The dramatic video captures the moment a lithium-ion battery fire breaks out inside the e-bike business. Within minutes, the owner responds using eFireX, knocking down the fire and preventing what could have been a catastrophic loss of property, inventory, and livelihood.

Lithium-ion battery fires are notoriously difficult to suppress, often burning hotter, reigniting repeatedly, and overwhelming conventional fire extinguishers that were never designed for these scenarios. As lithium-powered devices—including e-bikes, scooters, tools, electric vehicles, and energy storage systems—become more prevalent, fires tied to thermal runaway events are increasing in airlines, homes, businesses, and public spaces.

“This video is a textbook example of why preparation and having the right fire extinguisher for the situation matters,” said Jesse Corletto, founder of eFireX and a veteran firefighter. “The owner recognized the real fuel load inside his business—multiple lithium-ion batteries stored and charged under one roof—and made the decision to upgrade his fire protection strategy. That decision saved his business, literally within seconds. Every business and homeowner should evaluate their fuel load and if it includes lithium they should also add eFireX for their protection.”

Unlike traditional ABC extinguishers, which can be ineffective or even dangerous when used on lithium battery fires, eFireX utilizes its patented TRPL‑E™ encapsulating agent to rapidly extinguish the high heat output, cool and encapsulate the burning cells, and stop thermal runaway through a heat exchange process technology in the agent. In the Quebec incident, the fire was contained quickly and did not reignite—an outcome that is still uncommon in lithium battery events.

The footage offers rare, real-world proof that proper preparation and the right suppression technology can change that outcome and underscores a larger industry challenge: not all fire extinguishers perform equally when lithium-ion batteries are involved, and clear standards for testing and performance remain inconsistent.

“This incident reinforces the urgent need for standardized, validated testing procedures and performance benchmarks for lithium battery fire protection,” Corletto added. “As the public is increasingly exposed to this new fuel fire hazard risk, we need to ensure that solutions marketed for lithium fires actually work in real-world conditions.”

Too often, lithium battery fires result in total losses—especially in small businesses such as repair facilities, warehouses, and charging hubs—because fires escalate faster than responders can arrive. In many cases, thousands of gallons of water are required to put out the fire, tying up emergency resources and still failing to fully eliminate the risk of reignition.

“This isn’t a controlled test or a laboratory demonstration,” said Corletto. “This is a business owner facing a real emergency—and walking away with his building and business intact. Lithium battery risk is not a user behavior problem—it’s a containment problem. And that’s exactly what eFireX is designed to solve.”

eFireX | www.efirex.com

The Minnesota Public Utilities Commission approved Xcel Energy's CapacityConnect Phase 2, a utility-owned battery storage program that will add 50 to 200 megawatts to the energy grid. While the Commission did not move forward with a behind-the-meter virtual power plant program that would connect more customers and lower energy bills, its decision requires Xcel to quantify the benefits that the distributed batteries deployed through the program bring to the grid.  This groundbreaking analysis will set the stage for more fully and fairly valuing the benefits of local clean energy resources, like rooftop solar and batteries, in Minnesota.  

In particular, the Commission ordered Xcel to develop Xcel-specific estimates of the benefits these distributed energy resources provide to the energy grid by November 2027 and to submit the report as part of its Integrated Distribution Plan. Additionally, the order requires Xcel to submit a comprehensive evaluation plan within 180 days explaining how it will measure cost savings, grid benefits, and how these resources can best support both the larger power system and local networks. These requirements will produce the first Minnesota-specific, utility-developed framework for measuring the value of batteries connected to the energy grid and will help guide future CapacityConnect phases and how all future distributed energy resources are valued. 

Will Kenworthy, Vote Solar’s Midwest Regulatory Director, issued the following statement: 

“Approving Xcel’s CapacityConnect Phase 2 program marks positive progress in bringing more battery storage onto Minnesota’s energy grid, but Minnesota is still leaving meaningful energy bill savings on the table by not advancing a virtual power plant program that would help more customers maximize their energy resources. Still, this decision lays important groundwork for the future. By requiring Xcel to define the grid value of all types of distributed energy resources, Minnesota is taking a key step toward fully recognizing the value of local clean energy like solar.  

“Vote Solar will continue to work with partners to ensure distributed resources are fully valued and to accelerate the deployment of virtual power plants and other local clean energy solutions that can reduce emissions and lower energy costs for all.”

Vote Solar | https://votesolar.org/

On April 2, 2026, the Minnesota Public Utilities Commission approved Xcel Energy’s proposed “Capacity*Connect” (C*C) program (Docket #25-378), a significant step toward creating the grid of the future. This innovative program originally came out of Xcel’s Energy’s 2024 Integrated Resource Planning process and will deploy up to 200 megawatts of battery storage on Xcel’s distribution grid. 

“Fresh Energy applauds the Minnesota Public Utilities Commission's deep consideration of this issue and forward-looking decision,” said Will Mulhern, Director, Electricity at Fresh Energy. “This docket had many stakeholders and a robust record for the Commission to parse, and their final decision advances an innovative approach to bring much-needed clean energy capacity to the grid quickly, while optimizing benefits to its distribution system.” 

As utilities around the country grapple with growing capacity demands on their systems, distributed energy resources (DERs) can be a valuable tool for maintaining reliability, flexibility, and affordability while advancing decarbonization. Capacity*Connect will provide Xcel with an opportunity to learn how to coordinate DERs on its system in a way that works for its customers and advances decarbonization efforts. This learning will pave the way for further innovation and the adoption of additional DER programs in the future. It's clear that utilities around the country, including Xcel Energy, have a growing understanding that the DER model is viable, important, and in clear alignment with state policy goals. 

In Fresh Energy’s comments filed at the Commission, we supported the development of this program as a way to offset investment in new fossil fuel infrastructure and maximize the value of Xcel Energy’s existing grid. Additionally, because this program represents a large and long-term investment by the utility, we recommended that the Commission ensure Xcel Energy’s commitment to equitable implementation of this program are clear, ensuring it benefits environmental justice communities and diverse suppliers.  

“Fresh Energy is pleased with Xcel Energy and Sparkfund’s inclusion of several items that will allow small and diverse business owners to have the opportunity to bid on the Capacity*Connect contracts,” said Shubha Harris, Chief Equity Policy Officer at Fresh Energy. “This is a step in the right direction to allow more people to benefit from the investments in the clean energy economy.” 

The C*C program, which Xcel Energy would implement in partnership with deployment services company Sparkfund, is unique from other approaches in that it would leverage utility-owned and operated batteries on Xcel Energy’s distribution system. This allows Xcel Energy to control how the batteries are used, maximizing their ability to deliver capacity to the grid when it needs it most. This is one of a number of possible models for distributed energy programs. We are excited that the learnings from this program can pave the way to additional successful deployments in the future. 

Fresh Energy looks forward to continuing to engage with utilities, other stakeholders, and the Commission on advancing novel solutions to meet our state’s climate goals while delivering affordable and reliable service for Minnesotans.  

Fresh Energy | www.fresh-energy.org

The Minnesota Solar Energy Industries Association (MnSEIA), the Solar Energy Industries Association (SEIA), and the Coalition for Community Solar Access (CCSA) released the following statements responding to the Minnesota Public Utilities Commission’s approval of Xcel Energy’s Capacity*Connect distributed storage proposal.

Minnesota has a proud history of grid innovation, but the approved framework for Capacity*Connect represents a significant missed opportunity. While authorized as a pilot to inform future development, the program provides no meaningful pathway to collect comparative data from third-party developers or competitive market participants. By authorizing up to 200 megawatts of utility-owned batteries with a $430 million budget, the program shifts massive financial risks onto ratepayers while shutting out scalable, cost-effective, third-party clean energy solutions. Furthermore, the proceeding failed to incorporate the perspectives of independent developers or trade associations, sidelining industry expertise on interconnection and project development.

“Although we appreciate Xcel’s creative step toward investing in the distribution system, this is a flawed model,” said Sarah Whebbe, Director of Policy & Regulatory Affairs at MnSEIA. “Giving control to just one partner leaves out Minnesota's experienced solar and storage developers. A truly fair and equitable clean energy future requires open market competition, not a closed system that sidelines local businesses. This approach will add costs and limit the options of Minnesotans who want more clean energy choices.”

Guaranteed Profits at Ratepayer Expense

With this approval, Minnesota becomes the only state to adopt a distributed storage model that forces everyday ratepayers to cover the investment risk instead of leveraging private capital. Treated as utility-owned capital expenditures, Xcel Energy will earn a guaranteed profit. As a result, this is the only approved distributed storage program in the country with a cost-benefit ratio below one—meaning the costs quantifiably outweigh the benefits.

The approval process also suffered from a lack of transparency. During the hearing, Xcel introduced updated, unvetted financial calculations without prior distribution to intervening parties, preventing comprehensive review or display of the employed methodology.

“Xcel’s distributed storage program approved by the Minnesota Public Utilities Commission unfortunately bears little resemblance to other states’ storage programs that are proven to lower energy costs and increase grid reliability,” said Andrew Linhares, Midwest Director of State Affairs at SEIA. “Competitive markets for energy storage deployment ensure that ratepayers get the best, most affordable deal possible. The Capacity*Connect program takes the exact opposite approach – shifting the financial risk of projects to captive ratepayers who will be forced to pay for these projects regardless of performance.”

A Closed Pilot and a Double Standard

Positioning this program as a "pilot" misses the mark. By locking the state into an exclusive utility-owned model managed by a single partner, Sparkfund, Minnesota deprives itself of the comparative open-market data needed to scale efficiently.

Additionally, the Commission’s decision to exempt Xcel Energy from its own standard interconnection queue—citing that standard procedures would add costs and delay projects—highlights a glaring double standard, displacing projects and undercutting the rights of those already in the existing queue. If bypassing these standard processes is necessary to make utility projects viable, those same streamlined rules must be extended to all distributed energy resources.  

“Community solar and distributed storage developers have a proven track record of delivering affordable, resilient power to the grid while saving ratepayers money," said Nick Bowman, Senior Manager of Markets and Research at CCSA. “By severely limiting the opportunities for third-party developers to provide these exact same grid services for less, Capacity*Connect misses the mark. We need a modern, collaborative grid where customer-owned and third-party resources can compete fairly to deliver the absolute best value to Minnesotans.”

Minnesota Solar Energy Industries Association | www.mnseia.org

SEIA | www.seia.org

CCSA | https://www.communitysolaraccess.org