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Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems

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A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "A1: Smart Grids and Microgrids".

Deadline for manuscript submissions: 7 August 2026 | Viewed by 3404

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Prof. Dr. Il-Yop Chung

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Guest Editor

School of Electrical Engineering, Kookmin University, Seoul 02707, Republic of Korea
Interests: power system control and operation; renewable energy integration to grids; microgrids; power distribution systems; shipboard power systems
Special Issues, Collections and Topics in MDPI journals

Prof. Dr. Seon-Ju Ahn

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Guest Editor

Department of Electrical Engineering, Chonnam National University, Gwangju 61186, Republic of Korea
Interests: distribution system; distributed energy resources; microgrid; smart grid; real-time simulation
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Distributed energy resources (DERs) utilize various renewable energy sources to generate clean and sustainable electricity. They are also expected to enhance overall energy system efficiency through sector coupling with carriers like hydrogen and heat. The rapid increase in DER interconnections has begun to transform the traditional power grid.

DER generation, which once remained within local distribution networks, now influences neighboring networks and even the transmission system. Variations in DER output due to weather fluctuations can disrupt the supply–demand balance across the grid, increasing the risk of power system instability and widespread outages.

Addressing existing grid challenges while managing the uncertainty and variability introduced by DERs requires sophisticated control and operational strategies. To manage DERs efficiently, advanced management systems like DER Management Systems (DERMS) and Advanced Distribution Management Systems (ADMS) are essential. Further research is also needed on Distribution System Operator (DSO) and Transmission System Operator (TSO) structures and markets that effectively utilize these systems.

This Special Issue presents state-of-the-art research on control and operational techniques that enable the effective integration of DERs into various configurations of modern power grids. We welcome contributions focusing on novel coordination strategies, hierarchical control frameworks, and data-driven approaches that enhance grid flexibility, reliability, and resilience. Submissions addressing practical implementations, policy implications, and experiment-based validations are also strongly encouraged.

Prof. Dr. Il-Yop Chung
Prof. Dr. Seon-Ju Ahn
Guest Editors

Manuscript Submission Information

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Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

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Keywords

distributed energy resources
power distribution systems
integration of renewable energy resources
power system stability
flexibility
sector coupling
advanced distribution management systems (ADMS)
distributed energy resource management systems (DERMS)
non-wires alternatives (NWA)
microgrids
virtual power plants
demand response
distribution system operator (DSO)
TSO–DSO cooperation

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Related Special Issue

Advanced Control and Operation of Microgrids and Power Distribution Systems in Energies (9 articles)

Published Papers (6 papers)

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Research

22 pages, 3599 KB

Open AccessArticle

Coordinated Short-Term Scheduling and Control Integration in Microgrids Using Dual-Layer Deep Reinforcement Learning

by Kamelia Norouzi, Hao Xu and Wenxin Liu

Energies 2026, 19(10), 2465; https://doi.org/10.3390/en19102465 - 21 May 2026

Abstract

To optimize microgrid performance, both short-term and real-time operational objectives must be addressed, typically through energy scheduling and power control. Short-term scheduling maximizes the benefits of battery energy storage systems (BESS) by leveraging forecasted load and renewable generation conditions. However, real-time adjustments are required to account for prediction errors, as neglecting these can lead to a loss of short-term optimality and visibility in overall system performance. The challenge of coordinating scheduling with control remains underexplored due to the limited timescale difference and decoupling of optimization and control. To address this problem, a bi-level deep reinforcement learning (DRL) method is presented. The upper-level DRL optimizes short-term generation and charging/discharging schedules for synchronous generators (SGs) and BESS, respectively. The lower-level DRL implements the schedules while maintaining stability and optimality. The two DRL levels learn together in a dynamic environment to ensure the short-term and real-time operational objectives are well coordinated. Simulation results demonstrate the effectiveness of the proposed algorithm. The effectiveness of the proposed algorithm is demonstrated on the studied microgrid system. Extension to larger and more complex systems is considered as future work. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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25 pages, 660 KB

Open AccessArticle

Anchor-LS-Aided Voltage-Sensitivity Estimation and Voltage-Constrained Droop Allocation for VPP-Based Frequency Regulation

by Seungyeon Kim, Yeryeong Lee, Hyun Hwang and Jaewan Suh

Energies 2026, 19(10), 2393; https://doi.org/10.3390/en19102393 - 16 May 2026

Viewed by 104

Abstract

This paper proposes a voltage-sensitivity estimation and droop-allocation framework for virtual power plant (VPP)-based frequency regulation in partially observable distribution feeders. In practical distribution systems, active-power adjustments by distributed energy resources (DERs) for frequency regulation may cause voltage excursions, while full real-time feeder information is often unavailable. To address this issue, an anchor-least-squares (Anchor-LS)-aided sensitivity-estimation method is developed using only point-of-common-coupling (PCC) voltage measurements and feeder-network information. Unlike state-estimation-based, data-driven, or optimization-heavy approaches that typically require wider measurement coverage, large training datasets, or repeated centralized computation, the proposed framework is designed for fast VPP-based frequency regulation under partial observability using only limited PCC measurements and feeder information. The proposed method reconstructs an approximate operating point and derives an operating-point-sensitive PCC voltage-magnitude-sensitivity matrix based on a coupled Z-bus formulation. Based on the estimated sensitivity, a voltage-constrained asymmetric droop-allocation framework is developed for under-frequency and over-frequency events, together with a practical iterative droop-adjustment method that mitigates PCC voltage violations without relying on a full optimization-based dispatch model. The proposed framework is validated through two case studies. In Monte Carlo simulations on the IEEE 33-bus feeder, the proposed sensitivity model reduced the mean RMSE by about 117 times compared with the common-path resistance method and by about 30 times compared with the conventional Z-bus method. In simulations on a practical 115-bus Korean distribution feeder, the proposed method achieved acceptable droop capacities comparable to those of a centralized LP baseline while reducing the mean computation time by about 3.2 times for both under-frequency and over-frequency events. These results confirm the practical usefulness of the proposed framework for fast VPP-based frequency regulation in real distribution networks under partial observability. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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22 pages, 1792 KB

Open AccessArticle

Low-Carbon Economic Optimization and Collaborative Management of Virtual Power Plants Based on a Stackelberg Game

by Bing Yang and Dongguo Zhou

Energies 2026, 19(8), 1821; https://doi.org/10.3390/en19081821 - 8 Apr 2026

Viewed by 384

Abstract

To address the challenges of low-carbon economic optimization and collaborative management for multiple Virtual Power Plants (VPPs), this paper proposes a low-carbon economic optimization and collaborative management method based on a Stackelberg game framework. Firstly, a Stackelberg game model is constructed with the Distribution System Operator (DSO) as the leader and multiple VPPs as followers. The leader (DSO) guides the followers’ behavior through dynamic pricing strategies to maximize its own utility. Meanwhile, the followers (VPPs) develop energy management strategies to minimize their individual costs, taking into account factors such as energy transaction costs, fuel costs, carbon trading costs, operation and maintenance (O&M) costs, compensation costs, and renewable energy generation revenues. Furthermore, the strategy spaces of all participants are defined, and an optimization model is established subjected to constraints including energy balance, energy storage operation, power conversion, and flexible load response. The CPLEX solver and Nonlinear-based Chaotic Harris Hawks Optimization (NCHHO) algorithm are employed to solve the proposed game model. Simulation results demonstrate that the proposed method effectively facilitates collaboration between the DSO and multiple VPPs. While ensuring the safe operation of the system, it balances the profit between the DSO and VPPs, and incentivizes renewable energy consumption and indirect carbon reduction, thereby validating the effectiveness and superiority of the method and providing reliable technical support for the low-carbon collaborative operation of multiple VPPs. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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27 pages, 3072 KB

Open AccessArticle

Integration of Grid-Scaled Power-to-Heat Technology in Korea’s Power System: Operational Advantages and Future Insights for Renewable Energy Enhancement

by Yu-Seok Lee, Woo-Jung Kim, Seung-Hoon Jeong and Yeong-Han Chun

Energies 2026, 19(7), 1766; https://doi.org/10.3390/en19071766 - 3 Apr 2026

Viewed by 518

Abstract

Korea’s rising shares of variable renewable energy (VRE) and inflexible baseload increases the need for fast-responding and cost-effective flexibility. Most studies on power-to-heat (P2H) emphasize district-heating (DH) economics or load shifting, leaving the system-level impacts of its reserve provision capability unclear. We develop a mixed-integer linear programming model for reserve-constrained unit commitment (RCUC) that co-optimizes the power and DH systems. In addition, the model incorporates a P2H system capable of providing multiple reserve services. Reserve requirements are divided into static and dynamic terms, with the dynamic term represented as a piecewise-linear approximation of short-term VRE variability derived from weather-based generation profiles and evaluated at the scheduled VRE output. Using a 2030 winter week for Korea, we compare five cases: no EB; EB as load only; and EB contributing only to the secondary/regulation reserve requirement, only to the primary reserve requirement, or both. Under the KRW 1000/kWh curtailment-penalty case, EB as load reduces system operating cost compared to the baseline, and enabling reserve provision yields additional cost savings, with the largest benefit observed when primary reserve is provided. EB operation also shifts dispatch from coal and gas toward nuclear, VRE, and pumped storage, while reducing renewable curtailment. Overall, enabling P2H to contribute to reserve procurement, particularly in the primary reserve, delivers substantially greater value than representing P2H solely as a controllable load for energy shifting. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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28 pages, 8306 KB

Open AccessArticle

Coordinated Voltage and Power Factor Optimization in EV- and DER-Integrated Distribution Systems Using an Adaptive Rolling Horizon Approach

by Wonjun Yun, Phi-Hai Trinh, Jhi-Young Joo and Il-Yop Chung

Energies 2025, 18(23), 6357; https://doi.org/10.3390/en18236357 - 4 Dec 2025

Cited by 1 | Viewed by 749

Abstract

The penetration of distributed energy resources (DERs), such as photovoltaic (PV) generation and electric vehicles (EVs), in distribution systems has been increasing rapidly. At the same time, load demand is rising due to the proliferation of data centers and the growing use of artificial intelligence. These trends have introduced new operational challenges: reverse power flow from PV generation during the day and low-voltage conditions during periods of peak load or when PV output is unavailable. To address these issues, this paper proposes a two-stage adaptive rolling horizon (ARH)-based model predictive control (MPC) framework for coordinated voltage and power factor (PF) control in distribution systems. The proposed framework, designed from the perspective of a distributed energy resource management system (DERMS), integrates EV charging and discharging scheduling with PV- and EV-connected inverter control. In the first stage, the ARH method optimizes EV charging and discharging schedules to regulate voltage levels. In the second stage, optimal power flow analysis is employed to adjust the voltage of distribution lines and the power factor at the substation through reactive power compensation, using PV- and EV-connected inverters. The proposed algorithm aims to maintain stable operation of the distribution system while minimizing PV curtailment by computing optimal control commands based on predicted PV generation, load forecasts, and EV data provided by vehicle owners. Simulation results on the IEEE 37-bus test feeder demonstrate that, under predicted PV and load profiles, the system voltage can be maintained within the normal range of 0.95–1.05 per unit (p.u.), the power factor is improved, and the state-of-charge (SOC) requirements of EV owners are satisfied. These results confirm that the proposed framework enables stable and cooperative operation of the distribution system without the need for additional infrastructure expansion. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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16 pages, 3073 KB

Open AccessArticle

DER Interconnection Assessment Using ADMS for Stable Distribution System Operation

by Hyeong-Jin Lee, Jong-Nam Weon, Sung-Min Cho and Won-Wook Jung

Energies 2025, 18(22), 6045; https://doi.org/10.3390/en18226045 - 19 Nov 2025

Viewed by 1054

Abstract

As distributed energy resources (DERs) become increasingly integrated into distribution systems, ensuring safe and reliable interconnection has become a critical challenge. This study explores the use of an Advanced Distribution Management System (ADMS) as a technical review tool for DERs interconnection. The proposed approach enables users to reflect newly requested DERs into the operational analysis database and evaluate their impact using ADMS study mode. Key ADMS functionalities, including network modeling, load estimation, voltage analysis, and protection coordination checks, are described and applied to DERs interconnection scenarios. The study demonstrates that ADMS not only improves the reliability of technical assessments but also allows for automated evaluation of all criteria defined in the DERs interconnection technical guidelines—including thermal capacity, voltage impact, and protection coordination. This study demonstrates that stable operation of the distribution system can be achieved even with the increasing penetration of DERs, while also contributing to reduced reviewer workload and improved transparency and traceability. Full article

(This article belongs to the Special Issue Advanced Control and Operation of Distributed Energy Resources in Modern Power Systems)

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