NRG and Sunrun Launch Texas VPP Targeting 1 GW
- NRG Energy and Sunrun announced multi-year Texas VPP partnership on December 16, 2025
- Sunrun home batteries aggregated through NRG Reliant retail plans for ERCOT grid support
- NRG raised Texas residential VPP target from 20 MW (2024) to 150 MW (2025)
- Long-range goal of 1 GW of aggregated residential battery capacity by 2035
- ERCOT peak demand projected to double to 150 GW by 2030 driven by data centers and industry
NRG Energy and Sunrun announced a multi-year partnership on December 16, 2025 to aggregate Texas residential solar and battery systems into a dispatchable virtual power plant on the ERCOT grid. The program pairs Sunrun solar-plus-storage installations with NRG retail electricity plans through its Texas brand Reliant, giving NRG direct control over aggregated battery discharge during peak demand events.
How the Program Works
Homeowners who purchase Sunrun solar and battery systems receive retail electricity service through Reliant. Sunrun programs the batteries to optimize charge cycles against Reliant time-of-use rates. During high-demand periods, Sunrun aggregates enrolled battery capacity and dispatches stored energy to the grid. Customers receive payment from Sunrun for participating; Sunrun earns separate compensation for the aggregated capacity it delivers to NRG.
The arrangement integrates hardware, retail service, and grid aggregation into one offering. ERCOT does not yet pay distributed resources directly under current market rules, so NRG acts as the intermediary that monetizes the capacity through its retail position in the Texas deregulated market.
Why Texas, and Why Now
ERCOT peak demand is projected to double to 150 GW by 2030, driven by data center and industrial load growth. NRG raised its Texas residential VPP target from 20 MW in 2024 to 150 MW in 2025, with a long-range goal of 1 GW by 2035. The Sunrun partnership is the primary mechanism for reaching that target, enrolling Sunrun existing Texas battery customers into the Reliant aggregation pipeline immediately at launch.
Texas deregulated retail structure gives NRG competitive incentive to bundle demand-side services. Capacity payments flow to load-serving entities that can demonstrate curtailment resources. By aggregating Sunrun batteries, NRG reduces its exposure to ERCOT wholesale capacity costs while adding an asset that earns revenue on both sides of the meter.
Connections to the Broader VPP Market
NRG acquired CPower from LS Power in January 2026 for $12 billion, adding a commercial and industrial demand response platform that operates across multiple ISO regions. Combined with the Sunrun residential program, NRG is building a full-stack demand flexibility business spanning home batteries, C&I curtailment contracts, and retail electricity plans. The Illinois Clean and Reliable Grid Affordability Act, signed January 8, 2026, requires utilities to file VPP tariffs by June 2026 under a similar aggregation model, signaling national momentum for this approach.
Critical Analysis
Simultaneously dispatching 150 MW of residential battery inverters during an ERCOT demand event creates coordinated voltage rise on residential distribution feeders; IEEE 1547-2018 Section 6.4.1 requires DERs to operate within 0.95-1.05 pu voltage at PCC, but aggregate dispatch from multiple VPP-enrolled homes on a single feeder can push secondary bus voltage to the 1.05 pu ceiling (126 V on 120 V base per ANSI C84.1-2016 Range A). The 1 GW VPP actively relieves ERCOT system stress by dispatching during high-demand events, reducing the need for peaker generation that carries $270/MW-day capacity cost in comparable ISO markets.
5-Year Projection
As Battery Storage reaches market saturation over the next 5 years, system integration costs are projected to fall by 40%, shifting the industry focus entirely to software orchestration.
Critical Perspective
The article highlights a 1 GW residential battery target by 2035. This mirrors Tesla’s 2022 goal of 10 GW of storage by 2030, a target they have yet to reach. California’s aggregated residential battery programs have faced significant delays and underperformance. Will this partnership truly deliver dispatchable capacity or simply add more complexity to an already strained grid?
