Georgia Power Wins Approval for DERMS Deployment and 50 MW
- Power Quality Regulatory Voltage & Reactive Power
Marin Holt
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- 7 minutes read
- Georgia PSC approved DERMS deployment and 50 MW solar-plus-storage VPP pilot in July 2025
- Customer-directed VPP: $15/kW upfront plus $1.50/kWh performance; utility-directed: $750-$1,000/kW
- LMI and institutional customers receive enhanced incentives: $45/kW or $1,000/kW
- DERMS enables real-time DER monitoring, dispatch, and voltage optimization across distribution feeders
- IRP covers 2025-2044 with capacity RFPs and grid-enhancing technology evaluations
The Georgia Public Service Commission approved Georgia Power‘s 2025 Integrated Resource Plan in July 2025, greenlighting a distributed energy resource management system deployment alongside a 50 MW customer-sited solar-plus-storage virtual power plant pilot. The approval also includes a resilience program for large commercial and industrial customers that enables DER participation in demand response events while maintaining voltage stability on distribution feeders.
DERMS and VPP Program Structure
The DERMS platform will enable real-time monitoring and dispatch of distributed resources across Georgia Power’s service territory. The 50 MW solar-plus-storage VPP is split into two models: a 25 MW customer-directed program offering $15/kW upfront incentives with $1.50/kWh performance payments during dispatch events, and a 25 MW utility-directed model providing $750/kW upfront incentives for standard customers and $1,000/kW for low-to-moderate income and institutional participants. LMI customers in the customer-directed model receive enhanced incentives of $45/kW.
Voltage Management Implications
The DERMS deployment addresses a growing voltage regulation challenge on Georgia Power’s distribution system. As solar penetration increases across the SERC region, bidirectional power flows can cause voltage fluctuations that exceed ANSI C84.1 limits. The management system coordinates inverter-based resources to provide reactive power support, conservation voltage reduction, and real-time voltage optimization. The PSC also approved a formal process to evaluate grid-enhancing technologies for reliable integration of the state’s growing solar and battery storage fleet.
Critical Analysis
Aggregating 50 MW of customer-sited solar-plus-storage into a DERMS-coordinated VPP introduces coordinated inverter harmonic injection across Georgia Power distribution network. A 50 MW VPP can cause voltage rise on distribution feeders during maximum solar export, particularly on rural feeders where R/X ratios exceed 1.0, pushing voltage above ANSI C84.1 Range A limits.
5-Year Projection
Over the next 5 years, the deployment of DERMS Platform will shift from an isolated engineering challenge to a standard operational baseline, driving grid modernization.
Critical Perspective
Georgia Power’s 50 MW solar-plus-storage VPP pilot is approved. This 50 MW VPP is a fraction of the 1.5 GW of distributed solar already installed in California. The 2019 Texas winter storm demonstrated that aggregated distributed resources can fail under extreme conditions. Will this pilot truly improve grid resilience or simply add another layer of complexity to manage?
Why It Matters
Georgia Power’s approval establishes a regulatory model for utilities managing high DER penetration in the Southeast. The combined DERMS-VPP approach addresses both system-level voltage management and customer-facing distributed generation, setting pricing benchmarks that other SERC utilities may reference. The IRP covers the period from 2025 to 2044 and includes additional capacity RFPs, expanded renewable procurement, and grid-enhancing technology evaluations.
Implementation Architecture
Georgia Power’s DERMS deployment will coordinate distributed solar, battery storage, and demand response assets across its service territory through a centralized software platform capable of dispatching resources in response to grid conditions. The 50 MW solar-plus-storage VPP pilot targets residential and commercial customers who will receive incentive payments for allowing the utility to aggregate their behind-the-meter resources during peak periods. The pilot establishes a precedent in the SERC region, where vertically integrated utilities have been slower to adopt DER aggregation than their counterparts in restructured markets.
The Georgia Public Service Commission’s approval includes performance benchmarks that Georgia Power must meet within the first 18 months, including demonstrable peak load reduction of at least 25 MW from aggregated DER dispatch and system-wide voltage improvement of 2% at monitored distribution feeders. Failure to meet these benchmarks could affect cost recovery for the utility’s $45 million technology investment.
