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The never-ending issue of inadequate energy availability is constantly on the outermost layer. Consequently, an ongoing effort has been made to improve electric power plants and power system configurations. Photovoltaic Distributed Generators (PVDG) and compensators such as Distributed Static Var Compensator (DSVC) are the center of these recent advances. Due to its high complexity, these devices’ optimum locating and dimensions are a relatively new issue in the Electrical Distribution Grid (EDG). A modified version of Newton Raphson Based Optimizer (mNRBO) has been carried out to optimally allocate the PVDG and DSVC devices in tested IEEE 33 and 69 bus EDG. The mNRBO algorithm integrates four parameters to enhance NRBO’s performance by addressing its limitations in balancing exploration and exploitation. The article suggested novel Multi-Objective Functions (MOF), which have been considered to optimize concurrently the overall amount of active power loss (APL), voltage deviation (VD), relays operation time (TR ELAY ), as well as improve the coordination time interval (CTI) between primaries and backup relays set up in EDG. The proposed mNRBO algorithm surpasses its basic NRBO version, as long as another alternative algorithm, while providing very good results, such as minimizing the APL from 210.98 kW until 26.482 kW and 224.948 kW until 18.763 kW for the IEEE 33 and 69 bus respectively. Which proves the capability of the mNRBO algorithm of solving such power system challenges.

The growing concern for exponential load growth, depletion of conventional energy resources, security threats, and environmental concerns are compelling the development of efficient energy management tricks and techniques. These concerns have shifted the paradigm of renewable-based generation. These renewable energy-based electricity generations are mostly integrated into the distribution network as distributed generations (DGs). Therefore, an analysis of the impacts of DG placement while implementing Volt-VAr control (VVC) has been executed through the simultaneous application of conservation voltage reduction (CVR), DG, capacitor banks (CBs), and distributed static compensator (D-STATCOM). The combined application is called Volt-VAr-Watt control (VVWC), and the effectiveness of this method of control has been verified using techno-economic gain. Further, the exponential load model has been considered rather than considering the simple static load model. Five distinct operating scenarios have been tested under the proposed scheme of VVWC with IEEE-33 and IEEE-69 node systems. Rao-1 algorithm is adopted to select the optimal location and capacity for DG, CB and D-STATCOM. Static capacitors and D-STATCOM have been used as VAr compensating devices, and their integration with CVR has been tested distinctly. The simulation results indicate that the improvised results are obtained for D-STATCOM compared to static capacitors. The findings show that the integrated method of CVR, DG and D-STATCOM results in a significant techno-economic gain with reduced overall power consumption, line flows and network losses compared to the other cases.

In recent years, considerable growth was about the integration of renewable energy sources in the Radial Distribution Systems (RDS), as Photovoltaic Distributed Generators (PVDG) due to their importance in achieving plenty desired technical and economic benefits. Implementation of the Distribution Static Var Compensator (DSVC) in addition to the PVDG would be one of the best choices that may provide the maximum of those benefits. Hence, it is crucial to determine the optimal allocation of the devices (PVDG and DSVC) into RDS to get satisfactory results and solutions. This paper is devoted to solve the allocation problem (locate and size) of hybrid PVDG and DSVC units into the standards test systems IEEE 33-bus and 69-bus RDSs. Solving the formulated problem of the optimal integration of hybrid PVDG and DSVC units is based on minimizing the proposed Multi-Objective Function (MOF) which is represented as the sum of the technical-economic parameters of Total Active Power Loss (TAPL), Total Reactive Power Loss (TRPL), Total Voltage Deviation (TVD), Total Operation Time (TOT) of the overcurrent relays (OCRs) installed in the RDS, the Investment Cost of PVDGs (ICPVDG) and the Investment Cost of DSVCs (ICDSVC), by applying various recent metaheuristic optimization algorithms. The simulation results reveal the superiority and the effectiveness of the Slime Mould Algorithm (SMA) in providing the minimum of MOF, including minimization of the power losses until 16.209 kW, and 12.11 kVar for the first RDS, 4.756 kW and 7.003 kVar for the second RDS, enhancing the voltage profiles and the overcurrent protection system. Moreover, the ability to reach the optimal allocation of PVDG and DSVC and maintain the voltage profiles in the allowable limit, whatever the load demand variation.

The global power system is overloaded, resulting in a poor voltage profile, voltage instability, and large real and reactive power losses. Electrical power growth and hitching in providing required capacity provide a spur to appoint distributed generation (DGs) and static VAR compensator (SVC) options. This research shows how to use a genetic algorithm to optimize the integration of DGs and SVC in a distribution network for improved system performance by minimizing total real and reactive power losses. The 38-bus distribution test network, where GA is employed to solve the optimization problem, demonstrates the value of the proposed strategy. This paper assists individuals in working on the system performance of viability and building of future power grids, as well as a variety of scheme performance indicators from a higher social environment.

This study evaluates and compares centralized and distributed reactive power compensation strategies using Static Var Compensators (SVCs) to enhance the performance of a high-voltage transmission system in the Caribbean region of Colombia. The methodology comprises four stages: system characterization, assessment of the uncompensated condition under peak demand, definition of four SVC-based scenarios, and steady-state analysis through power flow simulations using DIgSILENT PowerFactory. SVCs were modeled as Thyristor-Controlled Devices (“SVC Type 1”) operating as PV nodes for voltage regulation. The evaluated scenarios include centralized SVCs at the Slack node, node N4, and node N20, as well as a distributed scheme across load nodes N51 to N55. Node selection was guided by power flow analysis, identifying voltage drops below 0.9 pu and overloads above 125%. Technically, the distributed strategy outperformed the centralized alternatives, reducing active power losses by 37.5%, reactive power exchange by 46.1%, and improving node voltages from 0.71 pu to values above 0.92 pu while requiring only 437 MVAr of compensation compared to 600 MVAr in centralized cases. Economically, the distributed configuration achieved the highest annual energy savings (36 GWh), the greatest financial return (USD 5.94 M/year), and the shortest payback period (7.4 years), highlighting its cost-effectiveness. This study’s novelty lies in its system-level comparison of SVC deployment strategies under real operating constraints. The results demonstrate that distributed compensation not only improves technical performance but also provides a financially viable solution for enhancing grid reliability in infrastructure-limited transmission systems.

Microgrids and their smart interconnection with utility are the major trends of development in the present power system scenario. Inheriting the capability to operate in grid‐connected and islanded mode, the microgrid demands a well‐structured protectional strategy as well as a controlled switching between the modes. This challenging task is dealt with in this study, by the proposed centralized smart mode transition controller (CSMTC). The controller embarks upon two major microgrid protection aspects, by incorporating the protectional strategy against unintentional islanding and auto‐reclosing. Subsequent to the protection of the microgrid, the smooth operation of the microgrid has also been a major focus of the proposed study. Therefore, the switching of microgrids between the modes (i.e. grid‐connected to islanded or vice‐versa) has been engaged in the proposed controller. Energy storage‐based distributed static synchronous compensator (E‐STATCOM) is integrated at the point of common coupling to support the performance of the controller. E‐STATCOM performs to compensate the switching transients, along with maintaining the steady‐state system stability. The CSMTC integrated with E‐STATCOM protects the microgrid against unwanted system faults and supports a seamless transition between the modes by controlling the interconnecting static switch. To verify the operation of the proposed control strategy, the microgrid test model is simulated on the podium of MATLAB 2015b/Simulink.

In this study, an improved direct power control strategy based on the deadbeat current control with adaptive ability is proposed for three-phase distribution static compensator (DSTATCOM), whose current references are directly computed by power reference and power feedback according to the instantaneous power theory, and the deadbeat current control is used to assure the current waveform quality. The improved direct power control strategy does not need phase-locked loop, and not exists the coupling among the control variables of DSTATCOM. Moreover, the proposed control strategy has good dynamic response and adaptive ability, and its design process is very simple. At last, the feasibility and validity of the proposed control strategy are verified by the simulation and experiment results.

The use of renewable energy such as wind power is one of the most affordable solutions to meet the basic demand for electricity because it is the cleanest and most efficient resource. In Algeria, the highland region has considerable wind potential. However, the electrical power system located is this region is generally not powerful enough to solve the problems of voltage instability during grid fault conditions. These problems can make the connection with the eventual installation of a wind farm very difficult and inefficient. Therefore, a wind farm project in this region may require dynamic compensation devices, such as a distributed-flexible AC transmission system (D-FACTS) to improve its fault ride through (FRT) capability. This paper investigates the implementation of shunt D-FACTS, under grid fault conditions, considering the grid requirements over FRT performance and the voltage stability issue for a wind farm connected to the distribution network in the Algerian highland region. Two types of D-FACTSs considered in this paper are the distribution static VAr compensator (D-SVC) and the distribution static synchronous compensator (D-STATCOM). Some simulation results show a comparative study between the D-SVC and D-STATCOM devices connected at the point of common coupling (PCC) to support a wind farm based on a doubly fed induction generator (DFIG) under grid fault conditions. Finally, an appropriate solution to this problem is presented by sizing and giving the suitable choice of D-FACTS, while offering a feasibility study of this wind farm project by economic analysis.

Stability of a standalone hybrid power system (HPS) in a smart grid is always a challenging task. Further, the operational stability of the power system depends on the associated communication infrastructure. Therefore, it is always crucial to pick up a controller that can assure system's stability along with performance, despite disturbances like (load and input wind variations) with communication delays. Present study focuses on reactive power management and voltage stability issues of an isolated HPS. The stability aspects of HPS are improved through reactive power compensation, by custom power devices like static var compensator. The control aspects of SVC as well as the whole hybrid system are taken care by H ∞ linear matrix inequalities approach. Further, H‐infinity control, Lyapunov stability along with linear matrix inequalities techniques estimate the delay boundary of controllers. The iterative performance of the proportional–integral–derivative controllers, and robust H ∞ damping controller of the HPS, are designed through LMI approach. Later experimental study of the HPS is done, with a prototype model in dSPACE real‐time control environment. In this case, dSPACE 1104 is added for data acquisition and control. Adaptability and robustness of the proposed controllers are verified under fluctuating loads and uncertain wind power input.

In this study, the significant effects of the load models used to analyse low‐voltage power systems are presented and a systematic process for selecting appropriate load compositions to evaluate the performance of distribution systems containing distributed generation is proposed. The driving force behind, and key reasons for, voltage instability are analysed by evaluating different load models subjected to grid disturbances. The stability conditions of distribution systems are also checked through time‐domain simulations performed on various network configurations, such as radial, loop, and mesh topologies. The system's responses to changes in the substation's voltage and contingency events are also demonstrated. It is found that the types and order of load models used greatly affect a system's voltage stability and therefore, an accurate load modelling is necessary to support the renewables integration in distribution systems. As the system's response is found to be sensitive to the network's topology and actual load composition, an approach that selects appropriate load compositions which, in turn, reduces the huge investment costs of improper planning, is proposed. The effectiveness of the proposed approach is verified by connecting static synchronous compensators to the network under varying load compositions.