Distributed Energy Resource Management Systems (DERMS) Market (2026-2036)

Distributed energy resources are now added faster than any other form of generating capacity, and most of them connect to networks that were designed to carry power in one direction only. According to the IEA Photovoltaic Power Systems Programme, 282 GW of distributed PV was installed worldwide in 2025, up from 228 GW in 2024, representing 41% of all PV added during the year. China added 159 GW, followed by Pakistan with about 14 GW, India with 12 GW, Germany with 9.2 GW, Brazil with 7.9 GW, and the U.S. with 7.6 GW. Cumulative distributed capacity reached 533 GW in China, 83 GW in Germany, 74 GW in the U.S., and 61 GW in Japan. At this scale, the distributed fleet changes how the grid operates, and DERMS becomes an operational requirement.

Storage and electrified loads are following solar behind the meter. Germany added 524,662 home battery systems in 2025, taking its stock to 2.22 million systems with about 25.5 GWh of capacity, according to the Marktstammdatenregister. In Australia, the Cheaper Home Batteries Program passed 507,000 installations in August 2026, about 13 months after its launch. Global electric car sales exceeded 20 million in 2025, a quarter of all new cars sold, and European heat pump sales rose 13% to about 2.88 million units. These resources become grid resources only when a platform can see and dispatch them.

The integration problem is already visible in system operation. AEMO recorded an all-time minimum operational demand of 9,666 MW in the National Electricity Market on 4 October 2025, and on 31 August 2026 rooftop solar met 99.9% of demand in South Australia. Germany recorded 573 hours of negative day-ahead prices in 2025, and ENTSO-E data show 1,223 negative-price hours across EU-27 bidding zones in the first quarter of 2026, compared with 593 a year earlier. In the U.S., Lawrence Berkeley National Laboratory reports about 1,312 GW of generation and 749 GW of storage waiting in interconnection queues at the end of 2025, with a median of about five years from request to operation. Uncontrolled distributed generation creates costs for the system and delays for new customers, and both are reduced when resources can be scheduled.

Thus, the rapid growth of distributed solar, storage, EVs, and heat pumps, together with the operating limits and congestion they are creating, is driving the growth of the DERMS market.

The rules that allow distributed resources to be aggregated and paid for grid services are now on fixed timetables in every major region, and each requires registration, telemetry, dispatch, and settlement systems delivered through DERMS and aggregation platforms. In the U.S., FERC Order No. 2222 requires each regional market to allow DER aggregations to participate in wholesale markets. CAISO is already compliant, NYISO is due to reach full compliance by the end of 2026, ISO New England is scheduled to implement its rules on 1 November 2026, PJM on 1 February 2028, MISO on 1 June 2029, and SPP in the second quarter of 2030. Each implementation date creates a new market in which aggregators need platforms that meet wholesale market standards.

State regulators are adding distribution-level requirements. In December 2024, the Illinois Commerce Commission approved the first grid plans under the Climate and Equitable Jobs Act, including USD 1.5 billion for ComEd and USD 83 million for Ameren, with investment in the systems needed to integrate DERs. In August 2024, the Massachusetts Department of Public Utilities approved the Electric Sector Modernization Plans of the state utilities, which fund the platforms needed to integrate DERs. Where a regulator directs or funds DERMS, the platform moves from a discretionary project into regulated grid investment, which is the most durable source of demand in this market.

The European Union has turned flexibility into a planning obligation. ACER approved the methodology for national flexibility needs assessments in July 2025, member states were due to submit their assessments by July 2026, and indicative national targets for non-fossil flexibility are due by January 2027. ACER submitted the draft network code on demand response to the European Commission in March 2025, and the European Grids Package of December 2025 adds guidance on flexible connection agreements. Other regions are following: Ofgem confirmed Elexon as market facilitator for local flexibility in Great Britain in June 2025, household batteries and EVs became eligible for the Japanese balancing market from April 2026, the AEMC rule on flexible trading in Australia commences on 1 November 2026, and the NDRC and NEA in China target more than 20 GW of VPP regulation capacity by 2027 and more than 50 GW by 2030.

Thus, the implementation of wholesale aggregation rules, distribution-level mandates, and national flexibility targets is driving the growth of the DERMS market.

Virtual power plants have moved from pilots to programs that dispatch hundreds of megawatts, and the platforms that enroll, forecast, and dispatch them form the largest software segment of this market. The U.S. Department of Energy estimated in January 2025 that VPP capacity in North America had grown to about 33 GW, and that the U.S. will need 80 to 160 GW by 2030, equivalent to 10% to 20% of peak load. The gap between current capacity and the stated need is larger than the entire current fleet, which indicates the scale of platform deployment required over the forecast period.

Individual platforms now operate at power plant scale. Voltus manages 8.5 GW of distributed capacity, and Uplight manages 8.5 GW of flexible load for more than 85 utilities. Kraken reported that its residential VPP passed 2 GW across more than 500,000 devices in July 2025, and the VPP of Origin Energy in Australia reached 1,589 MW at the end of June 2026. Sunrun reported in July 2026 that its California distributed power plant had reached up to 425 MW of peak dispatch capacity across more than 80,000 households, and in Texas the ERCOT aggregated DER pilot had 293 MW of qualified aggregations against a 500 MW cap in September 2026.

With performance proven, regulators are building VPPs into tariffs and resource plans. Virginia law requires Dominion Energy to propose a VPP pilot of up to 450 MW, the Colorado PUC approved a pay-for-performance VPP tariff for Xcel Energy in December 2025, and the Minnesota PUC approved up to 200 MW of utility-owned distributed batteries under Xcel Energy Capacity*Connect in April 2026. Once a VPP is part of a tariff or a resource plan, the platform that runs it becomes a long-term utility commitment.

Thus, the growth of VPP programs from pilots to dispatchable, tariff-based resources is driving the growth of the DERMS market, particularly the DER aggregation and VPP platforms segment.