In this paper, fault location on three-terminal and tapped transmission lines without requiring line parameters is presented, which mitigates the effect of line parameters variations due to weather and loading conditions on fault location accuracy. For three-terminal lines, a fault location method is presented which utilizes post-fault measurements of all three terminals. For tapped lines, two methods are presented. The first one uses post-fault measurements of the main two terminals. The second one needs one cycle of pre-fault measurements at main terminals as well. Synchronized transient-based measurements are used in methods proposed in this paper. In all presented methods, the fault location problem is converted to an optimization problem and then solved to find the line parameters and the accurate location of fault. The simulations are carried out by ATP/EMTP software and the presented algorithms are executed by MATLAB. Simulation results assess the effects of fault resistance, type and inception angle on the accuracy of presented methods. Further discussion is also provided on the impacts of synchronization errors, noisy measurements, and nonresistive faults.

An accurate algorithm for locating faults on two‐terminal transmission lines is presented in this study. The presented method does not require values of line parameters to locate the fault; therefore variation of line parameter values does not affect its accuracy. The method utilises synchronous post‐fault measurements of currents and voltages in both terminals and is based on the distributed time‐domain representation of transmission lines. Unlike conventional methods, fault location is converted to an optimisation problem. Then, this problem is solved by genetic algorithm to find the accurate location of fault. Furthermore, modifying the problem to be solved by the Newton optimisation method is discussed in this study. Simulation results performed by ATP/EMTP verify high accuracy of the presented method, and reveal that it is not significantly affected by fault resistance, fault type, fault inception angle and source impedance. Moreover, effect of measurement errors and synchronisation errors on the accuracy of presented method have been analysed which verify the efficiency of the algorithm in these conditions.

Distribution systems have traditionally received the least attention in the bulk picture of power systems; they are yet the most "critical component" as they directly impact customers’ perception and utilities’ reputation. While transmission systems have seen abundant literature, innovations, and applications of power electronic-based devices to optimize their performance, distribution systems still require more attention toward a flexible and dynamic scheme to cope with volatile energy consumption and production. As a replacement or enhancement of the traditional ones, Solid-State Transformers can play a central role in the energy management of distribution systems towards this goal, in addition to the mere voltage conversion. This manuscript, developed within the IEEE Task Force on Solid-State Transformer integration in distribution grids, offers a critical review of the Solid-State Transformer potential, services, and technical challenges for its integration in distribution systems. Particular attention is given to scientific trends and open points in the current research that must be addressed before utilities extensively integrate the Solid-State Transformer in distribution systems.

The risk of catastrophic wildfire has challenged our societies and impacted various industries with imminent danger to people's lives, financial burden, and irreparable damages to the environment, among other consequences. While progressive wildfires can impact power system operation and customer reliability and resilience, the relationship between power systems and wildfires is mutual: power systems can also contribute to wildfires. Wildfire risk of power systems is related to, in particular, fault-induced ignition events that can quickly turn into wildfires. While some electric utilities are working on approaches to mitigate such risk, the need for further research, development and demonstration of novel methodologies still exists. This paper identifies, analyzes, and compares the practices that can be further employed by utilities to manage the risk and mitigate the impact of power-system generated wildfires.

Behind-the-meter battery energy storage is used to mitigate non-dispatchability of customer-owned renewable sources. While serving their owners’ objectives, their underutilized capacities can be used to provide grid services to justify their cost. However, the integration of these resources extends the size and complexity of the network operation problem, imposing a processing burden on the central control system. In this paper, an agent-based distributed control framework is proposed that enables utilizing of the underutilized behind-the-meter capacities. In this framework, while the prosumer agents initially schedule their resources for daily cost management, a local customer aggregator agent performs day-ahead active and reactive power control on the underutilized behind-the-meter batteries to provide multiple grid services. A novel grouping algorithm is developed based on voltage sensitivity and a modified $k$-means clustering method to assign customer groups to the local agents and establish the network subsystems. Mixed-integer linear programming is used to model and solve multiple optimization problems. The proposed framework is applied to the 123-bus distribution network. The simulation results show its effectiveness in terms of complexity and optimality, compared to the central control approach in allocating the unused behind-the-meter resources for two common industry needs: network bottleneck congestion relief and grid-edge voltage support.