Virtual power plants (VPPs) are having a moment. While utility-scale projects wade through equipment backlogs and the mire of interconnection queues, distributed energy resource (DER) aggregation is gaining traction and scaling fast.
Earlier this month, ing signals from two California grid support programs, Sunrun and Tesla dispatched a record-setting 669 megawatts (MW) and 745 MW on consecutive evenings, the largest residential distributed power plant dispatches in U.S. history. The companies contributed more than 580 MW of customer-sited energy on September 9, the previous high mark, eclipsing the first-of-its-kind coordinated test of VPP capabilities by California utilities last summer, which dispatched about 539 MW and earned itself a dedicated Factor This podcast episode.
VPPs put downward pressure on real-time energy prices by giving grid operators the California Independent System Operator (CAISO) more headroom when electricity demand is high (looking at you, autumn heat waves). It’s a rare win for both utility and ratepayer. A new Brattle Group report finds that rapidly scaling such programs could cut expected household electricity bill increases by more than half over the next five years and provide utilities with hundreds of MW of dependable capacity.
Residential demand response currently represents approximately 1.1% of utility system peak demand on average, or about 10 gigawatts GW nationwide. However, the top 10% of VPP-friendly utilities claim about 4% system-peak contribution. If all utilities scaled to that level, Brattle estimates that roughly 25 GW of additional residential demand flexibility could generate $4 billion to $7 billion in annual benefits for American households and spare the owners of the poles and wires $65 million per year in distribution upgrade costs by the VPP’s first year of full-scale operation.
And if other parties aren’t interested in tapping into distributed energy, data centers will take the electrons. Sunrun, Everyday Electric (formerly Renew Home), and Tesla announced an agreement in June to form the country’s largest VPP, promising up to 16 GW of flexible energy capacity as a solution for hyperscalers and utilities.
“The grid of the 1800s cannot power the innovation of 2026,” Sunrun CEO Mary Powell noted. “Americans deserve innovation that does not create unnecessary energy costs.”
Recent VPP legislation is paving the way for increased adoption in several states, including Illinois, Massachusetts, Minnesota, and Virginia. The federal permitting reform bill released last month includes provisions for dispatchable energy systems.
All of this to say: If you’ve been looking at the nationwide capacity crunch and wondering who will keep the lights on, an emerging possibility is: we will. Big projects take time. Programs propping up DERs can be deployed much faster. Of course, figuring out who pays for what and how stakeholders are compensated is sticky, but the juice certainly seems worth the squeeze.
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Aligned Priorities
Clean energy asset manager Aligned Climate Capital has closed on approximately $387 million in construction-to-permanent financing for a 126 MW community solar portfolio spanning 20 projects across Illinois and Maryland. Apterra Infrastructure Capital led the facility, which finances each project’s construction and converts to permanent debt as it reaches operation.
The portfolio comprises about 115 MWdc across 18 sites in Illinois and 11 MWdc at two projects in Maryland, and is expected to generate around 225 million kilowatt-hours (kWh) annually, enough to power roughly 31,500 homes.
“We’re seeing an important shift in distributed energy,” noticed Peter Davidson, CEO of Aligned Climate Capital. “Individual projects may be too small for traditional infrastructure investors. But when you bring those projects together into a larger portfolio, you can attract institutional financing that would otherwise be difficult to access. That helps move more projects from development into operation.”
The Illinois projects are located in Ameren and ComEd utility territories, with a portion participating in the Illinois Shines Adjustable Block Program. The Maryland projects are located in Delmarva Power and Potomac Edison utility territories and participate in the state’s Community Solar Energy Generating Systems program, which reserves at least 40% of project capacity for low- and moderate-income subscribers.
The facility is supported by a lender syndicate composed of BankUnited, Stifel, Banco de Crédito e Inversiones, Amalgamated Bank, Siemens, Farmer Mac, and BTG Pactual. BankUnited is serving as depository agent, and BankUnited and Stifel are the interest rate swap providers. Banco de Crédito e Inversiones is the letter of credit provider. Clifford Chance acted as legal counsel for the borrower, and Norton Rose Fulbright served as legal counsel for the lenders.
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Bigger in Texas, you say?
To say the Electric Reliability Council of Texas (ERCOT) grid had a record-breaking 2026 would undersell it: ERCOT broke its daily peak load record on 34 separate days this summer. More impressive? The grid operator didn’t have to issue a single call for public energy conservation, and power prices stayed more or less in check.
ERCOT did it by dispatching batteries, which have been rapidly integrated into its system over the last few years. Texas’s primary grid operator’s installed storage capacity now exceeds 15 GW, nearly doubling from about 8 GW at the start of 2025.
Developer Nightpeak Energy just added another 150 MW to the mix, announcing the financial close and commercial operation of its two-hour duration Bocanova 2 battery storage project in Southeast Texas. Bocanova 2 is the second phase of Nightpeak’s battery storage development in Brazoria County, near the Houston metropolitan area. The first 150 MW phase began commercial operation in August 2025, meaning the site now boasts 300 MW capacity.
The Bocanova Power 2 project in Brazoria County, Texas. Courtesy: Nightpeak Energy
Bocanova 2 uses Tesla’s Megapack 2 XL battery storage systems and has a long-term offtake agreement with an unnamed “investment-grade counterparty.” The project was financed through a tax equity bridge loan and construction-to-term loan with MUFG Bank. U.S. Bank provided traditional tax equity.
“We’re seeing large loads come to the grid at a pace and scale that is fundamentally changing how the power sector plans for new demand. Texas is at the forefront of that growth, and meeting it will require significant new infrastructure as well as resources that can respond quickly as conditions change. With 300 MW now operating at Bocanova, we’re putting that kind of flexibility to work in one of the most dynamic power markets in the country,” summarized Paris Hays, co-founder and CEO of Nightpeak Energy.
Big Bucks for Big BESS
Flatiron Energy has closed on approximately $850 million of construction and term financing to support the Energizar Project in Chelsea, Massachusetts, a 1,200 megawatt-hour (MWh) battery energy storage system (BESS).
When Energizar reaches commercial operations by Q4 2027, it will be the largest BESS facility on the East Coast and one of the biggest urban storage facilities globally. The project will provide critical capacity and peaking energy resources for the local communities that rely upon the Boston grid.
“Energizar represents the culmination of years of work by many stakeholders. Projects of this complexity and scale only happen because of the support of the local community, policy makers, equipment and EPC providers, offtakers, and financing counterparties,” said Dan Myers, Flatiron’s chief financial officer. “We are incredibly grateful for such robust support and proud to contribute to the next phase of the region’s grid reliability and capacity resources.”
According to Flatiron, Energizar’s robust financing spans construction and bridge loan facilities, term loan facilities, letter of credit facilities, a preferred equity commitment, and a tax credit transfer commitment.
A consortium of banks provided the construction loans, term loans, bridge loans, and letters of credit, with Nord L/B, Santander, and Societe Generale serving as Coordinating Lead Arrangers; Investec and East West Bank serving as Joint Lead Arrangers; and Siemens Financial Services serving as Lender. East West Bank also acted as Depositary and Santander acted as Administrative Agent. The preferred equity commitment was provided by funds managed by a premier global credit asset manager with more than $350 billion of assets under management. Two Fortune 500 corporations committed to transfer a portion of the project’s ITCs.
Orrick, Herrington & Sutcliffe LLP and Foley Hoag LLP represented the Company. Winston Taylor LLP and Rath, Young and Pignatelli, P.C. represented the Lenders. CCA Capital LLC advised Flatiron with regard to the preferred equity investment and tax credit transfer. Riverside Risk Advisors acted as Hedge Advisor to Flatiron in connection with interest rate hedging activities. Raymond James Renewable Energy Investments advised the tax credit purchasers.
Waste not, Want not
Infrastructure company Ameresco has completed an innovative solar-plus-storage project at the main office of the Roseburg Urban Sanitary Authority (RUSA) in Roseburg, Oregon.
The $1 million project is the first element of a multi-phase energy program to enhance the resilience, sustainability, and cost-effectiveness of RUSA’s key facilities, including its wastewater treatment plant (WWTP) and natural treatment system (NTS).
The project includes a 39.4-kWDC solar photovoltaic system designed to generate about 51,580 kWh annually, offsetting 100% of the electricity used at RUSA’s main office. The solar array is paired with an 184-kWh battery energy storage system to ensure critical administrative and operational functions remain available during power disruptions.
The second and third projects include installing a 900-kW ground-mounted solar PV system at the WWTP and a 400-kW floating solar PV system at the NTS. Construction on these projects is anticipated to begin soon. The broader RUSA energy initiative has received significant regional recognition, including two 2026 Best of the Best Awards from the Oregon Association of Clean Water Agencies (ORACWA) and the 2026 Excellence in Resource Recovery & Sustainability Award from the Pacific Northwest Clean Water Association (PNCWA).
“Partnering with Ameresco allows us to modernize our facilities, safeguarding the long-term well-being of our community as a result,” said Jim Baird, general manager of RUSA. “Through smarter energy use and resilient infrastructure investments, we’re advancing reliable wastewater management while ensuring continued service for our customers in both everyday operations and critical situations.”
“Operating a wastewater treatment facility requires substantial energy consumption, which is why RUSA’s initiative and others it are so important to build a more efficient energy future,” added Louis Maltezos, co-president of Ameresco. “By working together, we’re showing how public organizations can adopt forward-looking strategies that cut emissions, lower costs, and strengthen the quality of life for the communities they serve.”
Sumber Artikel:
Renewableenergyworld.com
