Case Study Details - Future of Power Systems - Behind-the-meter battery integration

Behind-the-meter batteries installed at homes, commercial buildings, or industrial sites store electricity on the customer side of the meter, allowing users to manage when and how they consume or export energy. By shifting load, shaving peaks, and supporting self-consumption of on-site renewables, these systems reduce strain on the grid and help smooth local demand profiles. When paired with digital controls, behind-the-meter batteries can also participate in demand-response programs, aggregation schemes and virtual power plants (VPPs).

As electrification of end uses increases and renewable output becomes more variable, grid operators face rising challenges from peak loads, local congestion and system balancing. Analysis by the International Energy Agency (IEA) highlights that distributed batteries can provide fast and flexible response and support system stability without major grid upgrades.[1] When integrated into VPPs, behind-the-meter batteries can deliver services such as frequency regulation, peak reduction, reserve capacity and congestion management.

Main outcomes of the solution

Affordability: Lowers energy costs by reducing peak-demand charges, enabling time-shifting to lower-priced hours, and helping avoid or defer costly grid upgrades where local constraints would otherwise increase system costs.
Reliability & Flexibility: Enhances operational continuity by providing fast-response backup during outages or congestion, while enabling flexible dispatch of stored energy for self-consumption, load shifting and local balancing.
System Resilience: When aggregated and digitally coordinated, functions as distributed flexibility assets that support frequency stabilization, manage local constraints and reduce reliance on thermal peaker plants during extreme-weather events.

Key deployment and scaling factors

Analyze load profiles, tariff structures and usage patterns to size batteries correctly and maximize value streams.
Use standardized metering and communication protocols for seamless integration with energy-management systems, aggregators and grid operators.
Deploy advanced control systems to optimize charging and discharging in real time and coordinate safely with on-site renewables.
Ensure compliance with fire-safety codes, permitting requirements and interconnection standards for distributed batteries.
Create supportive regulatory frameworks enabling BTM batteries to participate in demand-response and grid-service markets.
Establish modular system designs and strong vendor partnerships to streamline rollout and asset management.
Address interconnection, protection and metering rules to enable safe import/export capability and VPP participation.

Case Studies

California Energy Commission and California Independent System Operator (CAISO) (2025), USA

California’s Demand-Side Grid Support (DSGS) program compensates households and aggregators that discharge behind-the-meter home batteries during grid stress events, such as heatwaves. DSGS has become a key element of California’s demand-side reliability strategy, complementing CAISO’s resource adequacy framework.[2]

In 2025, DSGS recorded its largest activation to date: over 100,000 home batteries delivered approximately 539 MW over two hours, demonstrating the scale and responsiveness of aggregated behind-the-meter resources.[3] Programme guidelines expanded available capacity to around 500 MW, enabling participation from aggregators including Sunrun, Tesla Energy, OhmConnect and others.

Under the program framework, aggregators coordinate battery dispatch, CAISO validates performance, and the program administrator Olivine manages settlement and compliance. DSGS is expected to deliver net system savings of approximately USD 28 million to USD 206 million over 2025–2028, depending on market conditions.[3] These savings are driven by avoided procurement of high-cost peak-generation resources and reduced reliance on emergency capacity measures during grid-stress events.

Iron Mountain Data Centers (2024), USA

In 2024, Iron Mountain Data Centers, in collaboration with the Virginia Department of Energy and with funding from the U.S. Department of Energy, initiated a project to deploy behind-the-meter battery energy storage at its Prince William County data center campus in Virginia. The project is supported by an award of approximately USD 50 million under DOE’s Grid Resilience and Innovation Partnerships (GRIP) program, with additional cost-sharing from private partners.

The battery system is installed on the customer side of the meter and is designed to support load management at a large, power-intensive data center site. The system will enable Iron Mountain to shift electricity consumption by charging during lower-cost periods and discharging during peak demand, reducing stress on the local distribution network and supporting more efficient use of grid infrastructure as on-site power demand grows.

In addition to load shifting, the battery is intended to improve site-level resilience by supporting critical IT operations during grid disturbances and reducing reliance on diesel backup generation during outages. The project is being used to assess how digitally controlled, behind-the-meter storage at hyperscale and enterprise data centers can contribute to both operational continuity and broader grid-flexibility objectives.

The initiative is structured as a replicable deployment model for other data-intensive campuses, providing insights into technical integration, regulatory coordination and the role of large behind-the-meter assets in supporting system reliability as electrification and data-center demand continue to expand.[4, 5]

References: