Power System Modeling and Control, 3rd Edition

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closed (20 August 2026)

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20 October 2026

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Topic Information

Dear Colleagues,

This Topic is a continuation of the previous successful Topic "Power System Modeling and Control”. The Topic seeks to collect innovative and multidisciplinary contributions related to the modeling, simulation, and control of technologies within power systems. The evolution of distributed generation, the large-scale integration of non-dispatchable renewable energy sources, energy storage systems, and electric mobility introduces new challenges in terms of system stability, robustness, and operational efficiency.

Submissions presenting novel control methods, advanced modeling techniques (both physics-based and data-driven), optimization strategies, and dynamic management solutions for power networks are particularly encouraged. The Topic spans both large-scale systems (e.g., transmission networks) and distributed contexts such as microgrids and Vehicle-to-Everything (V2X) environments, with applications across urban, industrial, and residential settings. This Topic encourages the submission of theoretical, experimental, simulation-based, and application-oriented studies, fostering cross-disciplinary and collaborative approaches, including not limited to the following aspects:

• Dynamic modeling and control of power systems;
• Integration of renewable energy sources and their impact on system stability;
• Analysis of power system in fault and unbalanced conditions;
• Control strategies for grid-forming and grid-following inverters;
• Predictive, adaptive, and robust control algorithms;
• Energy storage systems (BESS, V2G/V2H) and their management strategies;
• Coordination of distributed energy resources and smart grid operation;
• Digital twins, AI, and data-driven techniques for power system management;
• Autonomous and interconnected microgrids;
• Hierarchical and decentralized control schemes;
• Hardware-in-the-loop simulations and experimental validation.

Dr. Manuela Minetti
Dr. Mahmood Hosseini Imani
Dr. Andrea Mazza
Topic Editors

Keywords

Participating Journals

Journal Name	Impact Factor	CiteScore	Launched Year	First Decision (median)	APC
Applied Sciences applsci	2.9	6.1	2011	15 Days	CHF 2400	Submit
Designs designs	-	5.7	2017	19.5 Days	CHF 1600	Submit
Electronics electronics	2.9	7.0	2012	14.8 Days	CHF 2400	Submit
Energies energies	3.9	8.3	2008	16.7 Days	CHF 2600	Submit
Mathematics mathematics	2.3	5.4	2013	17.4 Days	CHF 2600	Submit

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Published Papers (5 papers)

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All Applied Sciences Designs Electronics Energies Mathematics

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27 pages, 2020 KB  

Open AccessArticle

An Approximate Single-Line-to-Ground Faulted Feeder Identification Method for 35 kV Resonant-Grounded Distribution Networks Based on Cross-State Apparent Admittance

by Jindong Yang, Shan Wang, Hongwen Liu, Siyi Yuan and Yang Xiang

Energies 2026, 19(14), 3416; https://doi.org/10.3390/en19143416 - 20 Jul 2026

Viewed by 268

Abstract

Single-line-to-ground (SLG) faults are the most frequent fault type in medium-voltage distribution networks. In 35 kV networks equipped with Y/Y/$\Delta$ transformers, the zero-sequence coupling with the transmission grid and inherent line asymmetry make reliable SLG faulted feeder identification highly challenging, especially under [...] Read more.

Single-line-to-ground (SLG) faults are the most frequent fault type in medium-voltage distribution networks. In 35 kV networks equipped with Y/Y/$\Delta$ transformers, the zero-sequence coupling with the transmission grid and inherent line asymmetry make reliable SLG faulted feeder identification highly challenging, especially under high fault resistance. To address these issues, this paper proposes an approximate cross-state apparent admittance method for identifying SLG faulted feeders in 35 kV asymmetric distribution networks. First, the pre-fault and post-fault zero-sequence current responses are analytically derived, accounting for the structural asymmetry of feeder phase-to-ground parameters and the neutral grounding branch. Then, a cross-state apparent admittance formulation is established using synchronized zero-sequence voltage and current phasors. Considering that the proposed criterion relies on the phase relationship of cross-state apparent admittances, its practical implementation requires a high-accuracy synchronized voltage and current measurement loop. Measurement-class CTs/PTs or equivalent high-precision acquisition channels are therefore recommended to ensure sufficient phase-angle accuracy for the admittance-plane criterion. For healthy feeders, the apparent admittance is represented by the inherent zero-sequence line-to-ground admittance under the adopted bus-voltage measurement configuration. For the faulted feeder, the nonlinear coupling term associated with the fault resistance is rigorously eliminated through system-level Kirchhoff’s current law analysis, yielding a fault-resistance-independent analytical expression. A quadrant-based identification criterion is subsequently developed in the complex admittance plane. Finally, a simulation model based on the real architecture and parameters of an actual 35 kV substation is established in PSCAD/EMTDC. The simulation case studies demonstrate that the proposed method can identify the faulted feeder under the tested severe-asymmetry and high-impedance fault conditions up to 10 k$\Omega$, provided that sufficiently accurate synchronized zero-sequence voltage and current phasors are available. In the simulation model, the zero-sequence voltage is measured at the bus or neutral grounding branch, and the feeder zero-sequence currents are measured at the outgoing feeder branches. Full article

(This article belongs to the Topic Power System Modeling and Control, 3rd Edition)

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41 pages, 1121 KB  

Open AccessArticle

Analytical Formulation and Equilibrium Structure of a 26-State Nonlinear Dynamical System for DFIG

by Abdullah Alassaf and Ibrahim Alsaleh

Mathematics 2026, 14(14), 2600; https://doi.org/10.3390/math14142600 - 17 Jul 2026

Viewed by 276

Abstract

We formulate and analyze a 26-dimensional nonlinear dynamical system governing a doubly-fed induction generator (DFIG) wind energy conversion system coupled to an infinite bus through a dynamic transmission line. Seven interacting subsystems—aerodynamics, a two-mass drivetrain, a fourth-order machine, rotor- and grid-side converter controllers, [...] Read more.

We formulate and analyze a 26-dimensional nonlinear dynamical system governing a doubly-fed induction generator (DFIG) wind energy conversion system coupled to an infinite bus through a dynamic transmission line. Seven interacting subsystems—aerodynamics, a two-mass drivetrain, a fourth-order machine, rotor- and grid-side converter controllers, a phase-locked loop, and a pitch regulator—are assembled into a single vector field $\dot{\mathbf{x}}=\mathbf{f}(\mathbf{x},\mathbf{u})$ on ${\mathbb{R}}^{26}$, derived in dimensionless coordinates. Strict positivity of the determinant $\mathrm{\Delta }=L_s{L}_r-L_m^2=\sigma L_s{L}_r$ for every physically admissible machine renders the flux–current map invertible, so the right-hand side is well defined; the nodal Kirchhoff constraint forms a semi-explicit differential-algebraic relation that we eliminate to obtain an explicit ordinary differential equation. The central contribution is a constructive scheme for the equilibria: the 26 stationarity conditions $\mathbf{f}({\mathbf{x}}^{\star },\mathbf{u})=\mathbf{0}$ are solved by an iterative voltage-matching procedure converging to a residual below ${10}^{-11}$ per unit—essentially machine precision—which removes the spurious start-up transients common in reported simulations. Analytically chosen feedback gains induce a hierarchy of well-separated time scales, placing the closed loop in the multiple-time-scale class; the separation is made quantitative through explicit small parameters ${\epsilon }_i$ formed from the ratios of subsystem time constants. Numerical integration of a GE $3.6$ MW configuration confirms the construction: under stationary forcing, the rotor speed stays within $1.32\times {10}^{-5}$ pu of the equilibrium, and under a large-amplitude wind program ($11\to 14\to 9$ m/s) spanning the full operating envelope, it is regulated to within $0.065\%$, while the DC-link voltage deviation remains below $2.4\times {10}^{-5}$ pu and the power balance closes with residual below ${10}^{-3}$ pu, the ≈2% mechanical–electrical gap being the modeled losses. Linearization about the computed equilibrium yields a Jacobian whose spectrum lies entirely in the open left half-plane, establishing local asymptotic stability and exposing the individual electromagnetic, torsional, and control modes. The model furnishes a rigorously initialized, analytically transparent basis for linearization, spectral stability analysis, and bifurcation study. Its practical value is that a consistent equilibrium and a certified spectrum remove the start-up transients and undocumented tuning that otherwise let initialization artifacts masquerade as genuine dynamics, so that the model can serve as a trustworthy building block for weak-grid and wind-farm stability studies. Full article

(This article belongs to the Topic Power System Modeling and Control, 3rd Edition)

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21 pages, 13929 KB  

Open AccessArticle

Modeling and Parameter Identification Algorithm for Tree-Contact Single-Phase-to-Ground Fault in Distribution Networks

by Zexi Chen, Pu Wang, Zijin Li, Yanxia Chen, Hongtao Li, Kaiwen Hu, Feng Su, Yaqi Yang and Heqi Wang

Energies 2026, 19(13), 2986; https://doi.org/10.3390/en19132986 - 25 Jun 2026

Viewed by 278

Abstract

The tree-contact single-phase-to-ground fault (TSF) in 10 kV distribution networks has high transition resistance, weak fault currents, and nonlinear steady-state waveforms. As existing high-impedance fault models cannot accurately describe its complete physical evolution, this paper proposes a novel modeling and parameter identification algorithm [...] Read more.

The tree-contact single-phase-to-ground fault (TSF) in 10 kV distribution networks has high transition resistance, weak fault currents, and nonlinear steady-state waveforms. As existing high-impedance fault models cannot accurately describe its complete physical evolution, this paper proposes a novel modeling and parameter identification algorithm for TSF. First, based on recorded data from full-scale experiments, the initiation and development processes of TSF are studied, revealing the main factors affecting fault electrical characteristics—such as moisture evaporation, pyrolysis carbonization, air gap breakdown, and tree body current dissipation. Then, a dynamic resistance series model for TSF is constructed, with parameters identified and calibrated using experimental data, objective functions, and physical constraints. Finally, a 10 kV TSF simulation model is built and verified. Furthermore, a cross-condition predictive validation is performed using different voltage and geometric boundaries. Results demonstrate that the proposed physics-constrained model can effectively reproduce the RMS fault current envelope with asymmetric moisture evaporation characteristics. It also accurately predicts steady-state nonlinear waveform features without parameter re-tuning, providing more physically consistent data support for future TSF identification studies. Full article

(This article belongs to the Topic Power System Modeling and Control, 3rd Edition)

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30 pages, 1910 KB  

Open AccessArticle

Online Voltage Control for Active Distribution Grids via Measurement Feedback Correction

by Qiang Wu, Ming Zhou, Hongwei Su, Yiwei Cui and Zhuangxi Tan

Electronics 2026, 15(5), 1031; https://doi.org/10.3390/electronics15051031 - 1 Mar 2026

Viewed by 576

Abstract

The increasing penetration of Distributed Energy Resources (DERs) in active distribution networks introduces significant voltage volatility. Traditional model-based control strategies often struggle to maintain voltage stability due to accurate parameter unavailability and time-varying topology. To address these challenges, this paper proposes a robust [...] Read more.

The increasing penetration of Distributed Energy Resources (DERs) in active distribution networks introduces significant voltage volatility. Traditional model-based control strategies often struggle to maintain voltage stability due to accurate parameter unavailability and time-varying topology. To address these challenges, this paper proposes a robust Measurement-Feedback Online Gradient Descent (MF-OGD) algorithm for real-time voltage regulation. Unlike conventional methods that rely on explicit network models, the proposed MF-OGD approach leverages real-time voltage measurements to correct gradient estimation errors, thereby implicitly compensating for both parametric mismatches and structural linearization inaccuracies. We provide rigorous theoretical guarantees for closed-loop stability and asymptotic tracking error under bounded disturbances. Furthermore, the framework is extended to a joint active–reactive power control scheme to ensure feasibility under severe operating conditions. Comprehensive simulations on the IEEE 33-bus and IEEE 69-bus standard test feeders validate the scalability and effectiveness of the proposed method. Numerical results demonstrate that the MF-OGD controller successfully maintains nodal voltages within the safety range, limiting the maximum voltage deviation to 0.022 p.u. even under 50% model parameter uncertainty. Additionally, the algorithm achieves a low tracking Root Mean Square Error (RMSE) of approximately 0.014 p.u. in the 69-bus system. Notably, the accumulated regret per node increases only marginally (from 0.032 to 0.038) as the network scale doubles, confirming the algorithm’s superior scalability and robustness compared to conventional open-loop baselines. Full article

(This article belongs to the Topic Power System Modeling and Control, 3rd Edition)

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21 pages, 956 KB  

Open AccessArticle

Stability Analysis of a Time-Delay Load Frequency Control System via an Improved Matrix-Separation-Based Inequality

by Fei Long, Haojie Du and Mo Li

Energies 2025, 18(21), 5614; https://doi.org/10.3390/en18215614 - 25 Oct 2025

Cited by 1 | Viewed by 844

Abstract

This study focuses on the stability of time-delay load frequency control (LFC) systems. Based on the Lyapunov–Krasovskii (L–K) functional method, a stability criterion with less conservatism and lower computational complexity is proposed. Unlike recent methods that decrease conservatism through enhancing the complexity of [...] Read more.

This study focuses on the stability of time-delay load frequency control (LFC) systems. Based on the Lyapunov–Krasovskii (L–K) functional method, a stability criterion with less conservatism and lower computational complexity is proposed. Unlike recent methods that decrease conservatism through enhancing the complexity of L–K functional, only the double integral is augmented in this paper. To estimate the L–K functional derivatives more precisely, an improved matrix-separation-based inequality is proposed, which introduces some delay-derivative-dependent matrices rather than the high-dimensional free matrices. By applying the augmented L–K functional and the improved matrix-separation-based inequality, the stability criterion is established. Case analysis demonstrates that the new stability criterion has less conservatism and lower computational complexity, thereby validating the correctness of the method presented. Full article

(This article belongs to the Topic Power System Modeling and Control, 3rd Edition)

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