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Advances in Power System Stability and Control
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Advances in Power System Stability and Control

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

Deadline for manuscript submissions: closed (31 August 2021) | Viewed by 14049

Special Issue Editors

Prof. Dr. Seon-Ju Ahn

E-Mail Website
Guest Editor
Department of Electrical Engineering; Chonnam National University, Gwangju 61186, Korea
Interests: power system control; real-time simulation; renewable energy; distributed generation; smart grid
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Hyun-Koo Kang

E-Mail Website
Guest Editor
Department of Electrical & Electronic Engineering, Hannam University, Daejeon, Korea
Interests: distributed energy resources; distribution system design, analysis and operation

Special Issue Information

Dear Colleagues,

Power system stability has always been a matter of importance, although different types of instability have emerged at different periods. Various control measures and devices have been developed and applied to the power system operation to maintain the stability. Over the last decade, new challenges have emerged that make the operation of power system complex and difficult. Widespread installation of renewable energy sources (RESs), such as photovoltaic and wind power, have considerably increased the uncertainty in power system operation. RES units, connected to the grid with power electronic converters, decreased the system inertia. Faster frequency dynamics in low inertia systems make power system operation and control more challenging.

This Special Issue aims therefore to encourage both academic and industrial researchers to present their latest findings on the advanced technologies and theories for the improvement of power system stability. The main topics of interest for this Special Issue include, but are not limited to:

  • Impact analysis of uncertain renewable energy sources on power system operation
  • Information and communication technologies for power system control
  • Application of artificial intelligence to power system operation
  • Advanced power electronics technologies
  • Control of HVDC for the improvement of dynamic stability
  • Energy storage system application for stability improvement
  • Synthetic inertia from renewable energy sources
  • PMU and wide area monitoring for power system control
  • Advanced energy management system
  • Advanced control theory for power system analysis and control

Prof. Dr. Seon-Ju Ahn
Prof. Dr. Hyun-Koo Kang
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

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.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • power system control
  • power system operation
  • power system stability
  • renewable energy resources
  • advanced control theory
  • low inertia system
  • uncertainty
  • power electronics application
  • wide area control

Published Papers (7 papers)

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Research

17 pages, 7221 KiB  
Article
Deep Learning-Based Adaptive Remedial Action Scheme with Security Margin for Renewable-Dominated Power Grids
by Yinfeng Zhao, Shutang You, Mirka Mandich, Lin Zhu, Chengwen Zhang, Hongyu Li, Yu Su, Chujie Zeng, Yi Zhao, Yilu Liu, Huaiguang Jiang, Haoyu Yuan, Yingchen Zhang and Jin Tan
Energies 2021, 14(20), 6563; https://doi.org/10.3390/en14206563 - 12 Oct 2021
Cited by 3 | Viewed by 1751
Abstract
The Remedial Action Scheme (RAS) is designed to take corrective actions after detecting predetermined conditions to maintain system transient stability in large interconnected power grids. However, since RAS is usually designed based on a few selected typical operating conditions, it is not optimal [...] Read more.
The Remedial Action Scheme (RAS) is designed to take corrective actions after detecting predetermined conditions to maintain system transient stability in large interconnected power grids. However, since RAS is usually designed based on a few selected typical operating conditions, it is not optimal in operating conditions that are not considered in the offline design, especially under frequently and dramatically varying operating conditions due to the increasing integration of intermittent renewables. The deep learning-based RAS is proposed to enhance the adaptivity of RAS to varying operating conditions. During the training, a customized loss function is developed to penalize the negative loss and suggest corrective actions with a security margin to avoid triggering under-frequency and over-frequency relays. Simulation results of the reduced United States Western Interconnection system model demonstrate that the proposed deep learning–based RAS can provide optimal corrective actions for unseen operating conditions while maintaining a sufficient security margin. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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25 pages, 4750 KiB  
Article
Short-Term Cooperative Operational Scheme of Distribution System with High Hosting Capacity of Renewable-Energy-Based Distributed Generations
by Chan-Hyeok Oh, Joon-Ho Choi, Sang-Yun Yun and Seon-Ju Ahn
Energies 2021, 14(19), 6340; https://doi.org/10.3390/en14196340 - 04 Oct 2021
Cited by 6 | Viewed by 1508
Abstract
As the interconnection of renewable-energy-based distributed generations (DGs) to the distribution system increases, the local and temporary voltage and current problems, which are difficult to resolve with the existing operation method, are becoming serious. In this study, we propose a short-term operational method [...] Read more.
As the interconnection of renewable-energy-based distributed generations (DGs) to the distribution system increases, the local and temporary voltage and current problems, which are difficult to resolve with the existing operation method, are becoming serious. In this study, we propose a short-term operational method that can effectively resolve voltage and current violations caused by instantaneous output fluctuations of DGs in a system with a high hosting capacity of renewable energy sources. To achieve the objectives, a modified heuristic network reconfiguration method, and a method determining the maximum power output limit of individual DGs are proposed. We propose a cooperative method for controlling the power output fluctuations of renewable-energy-based DGs, which includes voltage control, network reconfiguration, and power curtailment. The proposed algorithm was verified through case studies by using a test system implemented in MATLAB environments. It can effectively resolve violations caused by DGs while minimizing the number of switching operations and power curtailment. The proposed method is an appropriate operation method to be applied to the real system as it can cope with the instantaneous output fluctuation of DGs, which was not dealt with in the existing operation method. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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19 pages, 1316 KiB  
Article
Single-Machine Frequency Model and Parameter Identification for Inertial Constraints in Unit Commitment
by Sung-Eun Kim and Yeong-Han Chun
Energies 2021, 14(18), 5961; https://doi.org/10.3390/en14185961 - 20 Sep 2021
Cited by 1 | Viewed by 1387
Abstract
In recent years, the need for generation mixes that consider the inertial constraints in unit commitment (UC) has increased because the inertia of these systems has decreased with the increased use of renewable energy. In these circumstances, single-machine models can calculate the minimum [...] Read more.
In recent years, the need for generation mixes that consider the inertial constraints in unit commitment (UC) has increased because the inertia of these systems has decreased with the increased use of renewable energy. In these circumstances, single-machine models can calculate the minimum frequency and rate of change of frequency (RoCoF) at a high speed in terms of the characteristics of the changes in the generation mix, in order to identify the generation mixes that can satisfy inertial constraints. This study proposed methods to determine the parameters of the reduced frequency response (RFR) model, which is a single-machine model that considers the nonlinearity caused by restrictions on the generator’s output power, in order to apply inertial constraints to UC. The RFR models can include various forms of governor models and consider the nonlinear response characteristics of restrictions on the generator’s output power that change according to the scales of contingencies, system inertia, and changes in load characteristics through these parameters. From the simulations of real systems, it was observed that the parameters determined through the proposed methods achieved considerable accuracy in calculating the minimum frequency and RoCoF with the RFR model. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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22 pages, 1719 KiB  
Article
Enhanced Stability Criteria of Network-Based Load Frequency Control of Power Systems with Time-Varying Delays
by Wenxi Feng, Yanshan Xie, Fei Luo, Xianyong Zhang and Wenyong Duan
Energies 2021, 14(18), 5820; https://doi.org/10.3390/en14185820 - 14 Sep 2021
Cited by 9 | Viewed by 1415
Abstract
The stability problem for load frequency control (LFC) of power systems with two time-varying communication delays is studied in this paper. The one-area and two-area LFC systems are considered, respectively, which are modeled as corresponding linear systems with additive time-varying delays. An improved [...] Read more.
The stability problem for load frequency control (LFC) of power systems with two time-varying communication delays is studied in this paper. The one-area and two-area LFC systems are considered, respectively, which are modeled as corresponding linear systems with additive time-varying delays. An improved stability criterion is proposed via a modified Lyapunov-Krasovskii functional (LKF) approach. Firstly, an augmented LKF consisting of delay-dependent matrices and some single-integral items containing time-varying delay information in two different delay subintervals is constructed, which makes full use of the coupling information between the system states and time-varying delays. Secondly, the novel negative definite inequality equivalent transformation lemma is used to transform the nonlinear inequality to the linear matrix inequality (LMI) equivalently, which can be easily solved by the MATLAB LMI-Toolbox. Finally, some numerical examples are presented to show the improvement of the proposed approach. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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15 pages, 2602 KiB  
Article
Load Frequency Control of Multi-Region Interconnected Power Systems with Wind Power and Electric Vehicles Based on Sliding Mode Control
by Zhenghao Wang, Yonghui Liu, Zihao Yang and Wanhao Yang
Energies 2021, 14(8), 2288; https://doi.org/10.3390/en14082288 - 19 Apr 2021
Cited by 14 | Viewed by 1791
Abstract
In recent years, wind power systems have been used extensively, which not only improve the efficiency of current conventional power generation systems, but also can save traditional fossil fuel resources. However, considering the instability of wind power, after being grid connected, it can [...] Read more.
In recent years, wind power systems have been used extensively, which not only improve the efficiency of current conventional power generation systems, but also can save traditional fossil fuel resources. However, considering the instability of wind power, after being grid connected, it can easily cause an impact on the stability of the grid operation. Considering the above problems, this paper considers to make full use of the energy storage part of electric vehicles (EVs) to increase the stability of grid operation. Based on the mathematical model, this paper studies the load frequency control (LFC) problem of a multi-region interconnected power system with wind power and EVs. First, since the system states are difficult to be monitored, a state observer is designed to estimate the state. Based on this, the integral sliding mode controller (SMC) is designed to realize the LFC of the interconnected power system. Meanwhile, to obtain better control performance, this paper further analyzes and optimizes the controller parameters based on Lyapunov stability theory. At last, simulations are carried out for the power systems with two regions in Simulink. The results show that the designed controllers are effective to compensate the load demand disturbances. In addition, it is demonstrated that the battery storage of EVs can play the role of peak-shaving and valley-filling in LFC. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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33 pages, 11331 KiB  
Article
A Novel Structure of a Power System Stabilizer for Microgrids
by Jong Ju Kim and June Ho Park
Energies 2021, 14(4), 905; https://doi.org/10.3390/en14040905 - 09 Feb 2021
Cited by 16 | Viewed by 2022
Abstract
This paper proposes a novel structure of a power system stabilizer (PSS) to improve the stability of synchronous generators (SGs) in microgrids. Microgrids are relatively vulnerable in terms of stability due to their small size and low inertia. The rotational inertia and voltage [...] Read more.
This paper proposes a novel structure of a power system stabilizer (PSS) to improve the stability of synchronous generators (SGs) in microgrids. Microgrids are relatively vulnerable in terms of stability due to their small size and low inertia. The rotational inertia and voltage support of SGs are highly suitable for getting over the vulnerabilities of microgrids, but there exist weaknesses in low-frequency oscillations (LFOs) and limitations of synchronization due to electromagnetic characteristics. Therefore, we study how to accommodate the features of microgrids in the PSS of SGs and further enhance present advantages. The PSS proposed in this paper not only damps out LFOs by conventional lead-lag compensation but also provides additional damping torque according to the magnitude of the perturbation using a synchronous impedance characteristic (SIC). The proposed Lyapunov energy-function-based control strategy can also increase the synchronizing power of the SG to improve transient stability. For performance verification, we use parameters obtained by the particle swarm optimization (PSO) algorithm to compare the existing PSS with the proposed one and analyze them. The effect of the proposed micro-power system stabilizer (μPSS) is analyzed through frequency response analysis, and finally, small-signal stability analysis and the performance of transient stability are verified by time-domain simulation (TDS) on MATLAB/Simulink. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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15 pages, 5855 KiB  
Article
IEC 61850-Based Centralized Protection against Single Line-To-Ground Faults in Ungrounded Distribution Systems
by Soon-Ryul Nam, Woong-Hie Ko, Sopheap Key, Sang-Hee Kang and Nam-Ho Lee
Energies 2021, 14(3), 722; https://doi.org/10.3390/en14030722 - 30 Jan 2021
Cited by 7 | Viewed by 1920
Abstract
We developed an International Electrotechnical Commission (IEC) 61850-based centralized protection scheme to prevent single line-to-ground (SLG) faults in the feeders and busbars of ungrounded distribution systems. Each feeder intelligent electronic device (IED) measures its zero-sequence current and voltage signals and periodically transmits zero-sequence [...] Read more.
We developed an International Electrotechnical Commission (IEC) 61850-based centralized protection scheme to prevent single line-to-ground (SLG) faults in the feeders and busbars of ungrounded distribution systems. Each feeder intelligent electronic device (IED) measures its zero-sequence current and voltage signals and periodically transmits zero-sequence phasors to a central IED via a Generic Oriented Object Substation Event message. Using the zero-sequence phasors, the central IED detects SLG faults in feeders and busbars. To achieve centralized protection, angle differences between the zero-sequence currents and voltage phasors are exploited, and their calculation compensates for data desynchronization. The feeder IEDs were implemented using the MMS-EASE Lite library, while the transmitted zero-sequence phasors were calculated based on fault signals simulated by Power System Computer Aided Design / Electro-Magnetic Transient Design and Control (PSCAD/EMTDC). The central IED determined if the SLG fault was in a feeder or busbar by aggregating and analyzing the zero-sequence phasors received from the feeder IEDs. The results confirmed the validity and efficiency of our centralized protection scheme. Full article
(This article belongs to the Special Issue Advances in Power System Stability and Control)
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