Pub Date : 2024-10-04DOI: 10.1016/j.ijepes.2024.110285
This paper proposes a novel method to allocate distributed generation and energy storage as Microgrid-Forming Resources (MFR) to improve the reliability of medium voltage (MV) grids. A graph-based approach is used, which simplifies the circuit analysis and reduces computational time when compared to exhaustive search methods. First, a medium voltage substation-level Nodal Fault-Effect Matrix (NFEM) is derived from the feeder’s topology, which is used for predictive reliability calculations, and calibrated with historical data. Second, a reduced set of scenarios of MFR allocation are generated using a graph community approach and evaluated in terms of reliability improvement and power and energy requirements of the distributed resources. Two case studies are presented based on real grids with different reliability characteristics and the results indicate that the proposed approach is an insightful tool for distribution system planners to evaluate the integration of microgrids to improve system reliability.
{"title":"Allocation of Microgrid-Forming resources for distribution systems reliability improvement","authors":"","doi":"10.1016/j.ijepes.2024.110285","DOIUrl":"10.1016/j.ijepes.2024.110285","url":null,"abstract":"<div><div>This paper proposes a novel method to allocate distributed generation and energy storage as Microgrid-Forming Resources (MFR) to improve the reliability of medium voltage (MV) grids. A graph-based approach is used, which simplifies the circuit analysis and reduces computational time when compared to exhaustive search methods. First, a medium voltage substation-level Nodal Fault-Effect Matrix (NFEM) is derived from the feeder’s topology, which is used for predictive reliability calculations, and calibrated with historical data. Second, a reduced set of scenarios of MFR allocation are generated using a graph community approach and evaluated in terms of reliability improvement and power and energy requirements of the distributed resources. Two case studies are presented based on real grids with different reliability characteristics and the results indicate that the proposed approach is an insightful tool for distribution system planners to evaluate the integration of microgrids to improve system reliability.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426872","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-04DOI: 10.1016/j.ijepes.2024.110265
With the increasing share of wind power in the energy sector, many countries start to cut back supporting policies for wind power and shift towards market-oriented schemes, challenging the profitability of wind farms. Energy storage offers a flexible solution to enhance their profitability. This work explores different wind-related storage investment modes, including 1) direct ownership, 2) cooperative, and 3) competitive modes in a market-based environment. For the direct ownership mode, a bilevel single-leader-single–follower Stackelberg game model is proposed, where wind farms invest in and operate storage facilities strategically to maximize their profits in the upper level, while the lower-level problem represents the system operator’ s market-clearing process. A cooperative game framework is presented for the cooperative mode, that wind farms and storage investors agree on a profit allocation rule, i.e., Shapley value or Nucleolus to collaborate in investing and bidding as a coalition. The competitive mode is interpreted as a multi-leader-single-follower Stackelberg game, describing an independent investor investing in and operating storage facilities in competition with wind farms. Case studies conducted on a 6-bus and the IEEE 30-bus test systems demonstrate that storage facilities directly invested in by wind farms are the best option for maximizing their profits, resulting in up to an 8.7% increase. The cooperative option provides a suboptimal increase of up to 3.1%, diversifying the costs and risks associated with storage investments. In contrast, the competitive mode can diminish wind farms’ profitability, with up to a 30.6% decrease in profits.
{"title":"Assessment of wind-related storage investment options in a market-based environment","authors":"","doi":"10.1016/j.ijepes.2024.110265","DOIUrl":"10.1016/j.ijepes.2024.110265","url":null,"abstract":"<div><div>With the increasing share of wind power in the energy sector, many countries start to cut back supporting policies for wind power and shift towards market-oriented schemes, challenging the profitability of wind farms. Energy storage offers a flexible solution to enhance their profitability. This work explores different wind-related storage investment modes, including 1) direct ownership, 2) cooperative, and 3) competitive modes in a market-based environment. For the direct ownership mode, a bilevel single-leader-single–follower Stackelberg game model is proposed, where wind farms invest in and operate storage facilities strategically to maximize their profits in the upper level, while the lower-level problem represents the system operator’ s market-clearing process. A cooperative game framework is presented for the cooperative mode, that wind farms and storage investors agree on a profit allocation rule, i.e., Shapley value or Nucleolus to collaborate in investing and bidding as a coalition. The competitive mode is interpreted as a multi-leader-single-follower Stackelberg game, describing an independent investor investing in and operating storage facilities in competition with wind farms. Case studies conducted on a 6-bus and the IEEE 30-bus test systems demonstrate that storage facilities directly invested in by wind farms are the best option for maximizing their profits, resulting in up to an 8.7% increase. The cooperative option provides a suboptimal increase of up to 3.1%, diversifying the costs and risks associated with storage investments. In contrast, the competitive mode can diminish wind farms’ profitability, with up to a 30.6% decrease in profits.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426870","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-04DOI: 10.1016/j.ijepes.2024.110257
In order to accelerate the fault current transfer rate of hybrid DC circuit breaker (HDCCB) and reduce the cost. A novel full thyristors HDCCB combining vacuum and gas integrated series switch is proposed in this paper, which accelerates the fault current transferred. Moreover, the breaking of higher current levels and lower cost by using the full thyristors to replace the IGBT and other power electronic (PE) devices are realized. The operation of proposed HDCCB is analyzed in detail, and the theoretical numerical model is derived. With the key parameters optimized in terms of the operation HDCCB, the breaking current capability and the effectiveness are verified by the simulation model. Based on this, preliminary tests from a developed low-power prototype are presented and verified the performance of the proposed novel HDCCB.
{"title":"Development of a novel full thyristors hybrid DC circuit breaker combining vacuum and gas integrated series switch","authors":"","doi":"10.1016/j.ijepes.2024.110257","DOIUrl":"10.1016/j.ijepes.2024.110257","url":null,"abstract":"<div><div>In order to accelerate the fault current transfer rate of hybrid DC circuit breaker (HDCCB) and reduce the cost. A novel full thyristors HDCCB combining vacuum and gas integrated series switch is proposed in this paper, which accelerates the fault current transferred. Moreover, the breaking of higher current levels and lower cost by using the full thyristors to replace the IGBT and other power electronic (PE) devices are realized. The operation of proposed HDCCB is analyzed in detail, and the theoretical numerical model is derived. With the key parameters optimized in terms of the operation HDCCB, the breaking current capability and the effectiveness are verified by the simulation model. Based on this, preliminary tests from a developed low-power prototype are presented and verified the performance of the proposed novel HDCCB.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426871","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-03DOI: 10.1016/j.ijepes.2024.110253
This research introduces a new concept called Accelerating Virtual Rotor Control (AVRC) to address the challenges of low inertia and damping in a multi-source microgrid with combined Load Frequency Control (LFC) and Automatic Voltage Regulator (AVR). While existing controllers have shown effectiveness, they often suffer from complexity and impracticality in real-world applications, the AVRC offers simplicity and effectiveness; therefore, it has been applied to low- inertia microgrids (MGs) by incorporating Superconducting Magnetic Energy Storage (SMES) device for improved microgrid response. Nevertheless, the Phase-Locked Loop (PLL) usually suffers from the low bandwidth, which affects the system response, and stability in some cases. Consequently, a Proportional-Integral (PI) controller has been integrated into the VRC system, where the effects of the measurement delays in the PLL are mitigated. In terms of SMES response, PI controller can create a static error resulting an over charging/discharging issue. To overcome this effect, an integral feedback loop is added into the AVRC, resulting in a comprehensive control strategy known as PI-AVRC/I. Additionally, to achieve a better optimization performance for the parameters of the proposed control strategy, a modification has been introduced to the Zebra Optimization Algorithm (MZOA) using Levy Flight motion to enhance its global search capability and avoid local optima. A Hardware-In-the-Loop is demonstrated using a Real-Time Digital Simulator (RTDS) with the aid of RSCAD software in order to evaluate the efficacy of the proposed control strategy under different scenarios such as step load perturbations with/without high Renewable Energy Sources (RESs) integration, random domestic loads fluctuation, and Communication Time Delay (CTD). The results affirm the robustness of the proposed control strategy in maintaining frequency and voltage deviation withing favorable limits, especially with high RESs penetration.
{"title":"Accelerating virtual rotor control with integral feedback loop in low-inertia microgrids","authors":"","doi":"10.1016/j.ijepes.2024.110253","DOIUrl":"10.1016/j.ijepes.2024.110253","url":null,"abstract":"<div><div>This research introduces a new concept called Accelerating Virtual Rotor Control (AVRC) to address the challenges of low inertia and damping in a multi-source microgrid with combined Load Frequency Control (LFC) and Automatic Voltage Regulator (AVR). While existing controllers have shown effectiveness, they often suffer from complexity and impracticality in real-world applications, the AVRC offers simplicity and effectiveness; therefore, it has been applied to low- inertia microgrids (MGs) by incorporating Superconducting Magnetic Energy Storage (SMES) device for improved microgrid response. Nevertheless, the Phase-Locked Loop (PLL) usually suffers from the low bandwidth, which affects the system response, and stability in some cases. Consequently, a Proportional-Integral (PI) controller has been integrated into the VRC system, where the effects of the measurement delays in the PLL are mitigated. In terms of SMES response, PI controller can create a static error resulting an over charging/discharging issue. To overcome this effect, an integral feedback loop is added into the AVRC, resulting in a comprehensive control strategy known as PI-AVRC/I. Additionally, to achieve a better optimization performance for the parameters of the proposed control strategy, a modification has been introduced to the Zebra Optimization Algorithm (MZOA) using Levy Flight motion to enhance its global search capability and avoid local optima. A Hardware-In-the-Loop is demonstrated using a Real-Time Digital Simulator (RTDS) with the aid of RSCAD software in order to evaluate the efficacy of the proposed control strategy under different scenarios such as step load perturbations with/without high Renewable Energy Sources (RESs) integration, random domestic loads fluctuation, and Communication Time Delay (CTD). The results affirm the robustness of the proposed control strategy in maintaining frequency and voltage deviation withing favorable limits, especially with high RESs penetration.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142427332","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-03DOI: 10.1016/j.ijepes.2024.110259
When large-sized oil pipelines are subjected to skin effect heating under the constraint of limited current, the power supply converter must provide a higher current frequency. However, an inappropriate frequency can lead to increased energy losses and consequently reduce heating efficiency. To achieve higher heating efficiency of large-sized pipelines, this paper proposes a temperature control strategy based on optimal frequency forecast. First, a skin effect heating model is established to illustrate the necessity of frequency forecasting. Then, using the small sample data from the oil field, an optimal frequency forecasting method based on Gradient Boosting Decision Tree (GBDT) is proposed. At the forecasted frequency, a dual closed-loop control strategy for current and temperature, based on a designed three-phase converter, is employed to achieve temperature control under limited current conditions. The feasibility and effectiveness of this approach are demonstrated through a case study involving a 159 mm oil pipeline with a heating current of less than 80A. The experiment shows that with the forecasted frequency, the pipeline temperature reached 40 °C within 14 min, and the energy consumption per unit length of the pipeline is 394 W/m, complying with the standard Q/SY 06022-2016.
{"title":"Research on the current frequency forecasting of a power supply converter for heating the oil pipeline based on gradient boosting decision tree","authors":"","doi":"10.1016/j.ijepes.2024.110259","DOIUrl":"10.1016/j.ijepes.2024.110259","url":null,"abstract":"<div><div>When large-sized oil pipelines are subjected to skin effect heating under the constraint of limited current, the power supply converter must provide a higher current frequency. However, an inappropriate frequency can lead to increased energy losses and consequently reduce heating efficiency. To achieve higher heating efficiency of large-sized pipelines, this paper proposes a temperature control strategy based on optimal frequency forecast. First, a skin effect heating model is established to illustrate the necessity of frequency forecasting. Then, using the small sample data from the oil field, an optimal frequency forecasting method based on Gradient Boosting Decision Tree (GBDT) is proposed. At the forecasted frequency, a dual closed-loop control strategy for current and temperature, based on a designed three-phase converter, is employed to achieve temperature control under limited current conditions. The feasibility and effectiveness of this approach are demonstrated through a case study involving a 159 mm oil pipeline with a heating current of less than 80A. The experiment shows that with the forecasted frequency, the pipeline temperature reached 40 °C within 14 min, and the energy consumption per unit length of the pipeline is 394 W/m, complying with the standard Q/SY 06022-2016.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142427333","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-02DOI: 10.1016/j.ijepes.2024.110262
As grid-connected renewable energy and HVDC transmission grow in China, maintaining stable power grid operation is essential to avert system collapse caused by insufficient reserves of dynamic reactive power. Network topology and dynamic reactive power compensation device settings influence the transient voltage stability. Synchronous condenser (SC) serves as a dynamic reactive power source in modern energy AC/DC grids. However, the traditional SC excitation control strategy causes significant voltage overshoot during the voltage recovery process of the grid. This paper proposes a proportion-integral–differential-acceleration (PIDA) excitation controller which considers grid voltage feedforward for SC to improve FV type excitation control strategy to suppress transient voltage fluctuations, and the fruit fly optimization algorithm (FOA) is employed to tune the PIDA parameters. To verify the control effect, an improved IEEE14-node AC/DC hybrid system is proposed by using the PSCAD/EMTDC simulation platform, and variations in SC excitation voltage, DC transmission active power, reactive power output of SC (), and AC bus voltage on the inverter side are compared and analyzed in three different excitation control strategies under three fault conditions. Simulation results show that the improved SC excitation control strategy proposed can not only suppress system bus voltage drop effectively and reduce the risk of DC commutation failure, but also reduce voltage overshoot by 6 % and voltage drop by 10 % compared with those of traditional excitation control strategies of SC, and make the system recover faster and effectively improve the power system voltage level and voltage stability.
{"title":"Research on impact of synchronous condenser excitation strategy based on PIDA controller and feedforward voltage control on transient voltage of grid","authors":"","doi":"10.1016/j.ijepes.2024.110262","DOIUrl":"10.1016/j.ijepes.2024.110262","url":null,"abstract":"<div><div>As grid-connected renewable energy and HVDC transmission grow in China, maintaining stable power grid operation is essential to avert system collapse caused by insufficient reserves of dynamic reactive power. Network topology and dynamic reactive power compensation device settings influence the transient voltage stability. Synchronous condenser (SC) serves as a dynamic reactive power source in modern energy AC/DC grids. However, the traditional SC excitation control strategy causes significant voltage overshoot during the voltage recovery process of the grid. This paper proposes a proportion-integral–differential-acceleration (PIDA) excitation controller which considers grid voltage feedforward for SC to improve FV type excitation control strategy to suppress transient voltage fluctuations, and the fruit fly optimization algorithm (FOA) is employed to tune the PIDA parameters. To verify the control effect, an improved IEEE14-node AC/DC hybrid system is proposed by using the PSCAD/EMTDC simulation platform, and variations in SC excitation voltage, DC transmission active power, reactive power output of SC (<span><math><mrow><msub><mi>Q</mi><mrow><mi>sc</mi></mrow></msub></mrow></math></span>), and AC bus voltage on the inverter side are compared and analyzed in three different excitation control strategies under three fault conditions. Simulation results show that the improved SC excitation control strategy proposed can not only suppress system bus voltage drop effectively and reduce the risk of DC commutation failure, but also reduce voltage overshoot by 6 % and voltage drop by 10 % compared with those of traditional excitation control strategies of SC, and make the system recover faster and effectively improve the power system voltage level and voltage stability.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426867","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-02DOI: 10.1016/j.ijepes.2024.110264
The weak characteristics of high-impedance faults and the complex attributes of cross-country faults make faulty feeder detection of cross-country high-impedance faults difficult in medium-voltage networks. This paper deduces the zero-sequence equivalent circuit of cross-country faults through a three-sequence two-port network, analyzes the influence of grounding resistance on cross-country faults, and then explores the limitations of the traditional passive feeder detection methods. Moreover, this paper proposes a novel faulty feeder detection method for cross-country high-impedance faults based on zero-sequence active power regulation. First, based on the zero-sequence current varying characteristics under the regulation of zero-sequence voltage, construct a continuous adjustment region of zero-sequence voltage within the feeder insulation tolerance range. Next, based on the zero-sequence active power varying characteristics in each feeder, propose a discriminant formula for the zero-sequence active power fluctuation coefficient. Finally, adjusting zero-sequence voltage can actively amplify the differences in zero-sequence active power fluctuations between healthy feeders and faulty feeders and accurately select faulty feeders of cross-country high-impedance faults in medium-voltage networks. Various fault conditions are simulated in the PSCAD/EMTDC simulation and field test to verify the effectiveness of the proposed method. The proposed method can accurately identify all faulty feeders of cross-country high-impedance faults in the medium-voltage distribution network.
{"title":"High-impedance faulty feeder detection for cross-country faults in distribution networks based on zero-sequence active power regulation","authors":"","doi":"10.1016/j.ijepes.2024.110264","DOIUrl":"10.1016/j.ijepes.2024.110264","url":null,"abstract":"<div><div>The weak characteristics of high-impedance faults and the complex attributes of cross-country faults make faulty feeder detection of cross-country high-impedance faults difficult in medium-voltage networks. This paper deduces the zero-sequence equivalent circuit of cross-country faults through a three-sequence two-port network, analyzes the influence of grounding resistance on cross-country faults, and then explores the limitations of the traditional passive feeder detection methods. Moreover, this paper proposes a novel faulty feeder detection method for cross-country high-impedance faults based on zero-sequence active power regulation. First, based on the zero-sequence current varying characteristics under the regulation of zero-sequence voltage, construct a continuous adjustment region of zero-sequence voltage within the feeder insulation tolerance range. Next, based on the zero-sequence active power varying characteristics in each feeder, propose a discriminant formula for the zero-sequence active power fluctuation coefficient. Finally, adjusting zero-sequence voltage can actively amplify the differences in zero-sequence active power fluctuations between healthy feeders and faulty feeders and accurately select faulty feeders of cross-country high-impedance faults in medium-voltage networks. Various fault conditions are simulated in the PSCAD/EMTDC simulation and field test to verify the effectiveness of the proposed method. The proposed method can accurately identify all faulty feeders of cross-country high-impedance faults in the medium-voltage distribution network.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426866","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-01DOI: 10.1016/j.ijepes.2024.110273
The integration of renewable energy into the power grid poses significant challenges for optimization and scheduling of the power system. In recent years, methods based on deep reinforcement learning have surpassed traditional methods on the high complexity and long-term decision-making of power system optimization and scheduling. However, faced with the inherent uncertainty of renewable energy generation and the different optimization objectives in power system, the deep reinforcement learning methods are unable to effectively address them. This paper proposes a method that combines meta reinforcement learning with multi-agent reinforcement learning to solve the multi-objective two-stage robust optimization of wind/PV/thermal power system. We conducts optimization and scheduling experiments on the IEEE39 bus system. The results indicate that our method not only enhances the robustness of the scheduling strategy, but also outperforms baseline methods in terms of convergence, diversity, and uniformity of the Pareto frontier.
{"title":"Multi-objective two-stage robust optimization of wind/PV/thermal power system based on meta multi-agent reinforcement learning","authors":"","doi":"10.1016/j.ijepes.2024.110273","DOIUrl":"10.1016/j.ijepes.2024.110273","url":null,"abstract":"<div><div>The integration of renewable energy into the power grid poses significant challenges for optimization and scheduling of the power system. In recent years, methods based on deep reinforcement learning have surpassed traditional methods on the high complexity and long-term decision-making of power system optimization and scheduling. However, faced with the inherent uncertainty of renewable energy generation and the different optimization objectives in power system, the deep reinforcement learning methods are unable to effectively address them. This paper proposes a method that combines meta reinforcement learning with multi-agent reinforcement learning to solve the multi-objective two-stage robust optimization of wind/PV/thermal power system. We conducts optimization and scheduling experiments on the IEEE39 bus system. The results indicate that our method not only enhances the robustness of the scheduling strategy, but also outperforms baseline methods in terms of convergence, diversity, and uniformity of the Pareto frontier.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426869","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-01DOI: 10.1016/j.ijepes.2024.110248
The integration of variable renewable energy supplies into smart grid energy management poses several obstacles to system operation. An efficient solution for resource management is essential to ensuring reliable operation. This research presents distributed robust asso-model predictive control () as a way to handle energy problems in a multi-layer and multi-time frame optimization method. The is a hierarchical system that integrates a centralized supervisory management () layer for long-term optimization with a distributed coordination management () layer for short-term adaptation to high power fluctuations. The higher layer, known as the , is responsible for providing the grid operator with specific operating plans and offering guidance to the bottom layer, known as the . The is responsible for coordinating the interaction between the centralized optimization goals and the physical power system layer. Furthermore, a distributed extended Kalman filter () is used to ascertain the inter-dependencies among subsystems. Next, an iterative approach based on ash optimization is proposed to get the globally optimum solution of the whole system in a partly distributed manner. The simulation results demonstrate the effectiveness of the proposed control approach, which combines the advantages of centralized and distributed control to provide a comprehensive solution for the grid operating issue. To verify and assess the effectiveness of the suggested approach, the acquired outcomes are compared to those of the centralized robust, distributed robust, and distributed approaches. The simulation findings confirm the practicality of using the suggested system to manage future smart grid assets.
{"title":"Distributed robust Lasso-MPC based on Nash optimization for smart grid: Guaranteed robustness and stability","authors":"","doi":"10.1016/j.ijepes.2024.110248","DOIUrl":"10.1016/j.ijepes.2024.110248","url":null,"abstract":"<div><div>The integration of variable renewable energy supplies into <em>smart grid</em> energy management poses several obstacles to system operation. An efficient solution for resource management is essential to ensuring reliable operation. This research presents distributed robust <span><math><mi>L</mi></math></span>asso-model predictive control (<span><math><mi>D − RLMPC</mi></math></span>) as a way to handle energy problems in a <em>multi-layer</em> and <em>multi-time</em> frame optimization method. The <span><math><mi>D − RLMPC</mi></math></span> is a hierarchical system that integrates a centralized <em>supervisory management</em> (<span><math><mi>SM</mi></math></span>) layer for long-term optimization with a distributed <em>coordination management</em> (<span><math><mi>CM</mi></math></span>) layer for short-term adaptation to high power fluctuations. The higher layer, known as the <span><math><mi>SM</mi></math></span>, is responsible for providing the grid operator with specific operating plans and offering guidance to the bottom layer, known as the <span><math><mi>CM</mi></math></span>. The <span><math><mi>CM</mi></math></span> is responsible for coordinating the interaction between the centralized optimization goals and the physical power system layer. Furthermore, a <em>distributed extended Kalman filter</em> (<span><math><mi>DEKF</mi></math></span>) is used to ascertain the inter-dependencies among subsystems. Next, an iterative approach based on <span><math><mi>N</mi></math></span><em>ash optimization</em> is proposed to get the globally optimum solution of the whole system in a partly distributed manner. The simulation results demonstrate the effectiveness of the proposed control approach, which combines the advantages of centralized and distributed control to provide a comprehensive solution for the grid operating issue. To verify and assess the effectiveness of the suggested approach, the acquired outcomes are compared to those of the <em>centralized robust</em>, <em>distributed robust</em>, and <em>distributed</em> <span><math><mi>MPC</mi></math></span> approaches. The simulation findings confirm the practicality of using the suggested system to manage future smart grid assets.</div></div>","PeriodicalId":50326,"journal":{"name":"International Journal of Electrical Power & Energy Systems","volume":null,"pages":null},"PeriodicalIF":5.0,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142426868","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-09-29DOI: 10.1016/j.ijepes.2024.110263
To address the problems of poor speed performance and the large influence of the distributed capacitance of traditional pilot differential protection, a pilot protection scheme based on the characteristics of the transient voltage waveform is proposed. First, the expression of the relationship between the fault voltage of the current-limiting reactor and the measuring point is derived. From the theoretical derivation, it can be inferred that for internal faults, the voltage ratio of the current-limiting reactor to the measuring point on both sides of the HVDC line is constant over a short period. For external faults, the voltage ratio of the current-limiting reactor to the measuring point varies exponentially on the fault side, while on the other side, it remains constant. Based on the above characteristics, the waveform characteristics of the voltage ratio of the current-limiting reactor to the measuring point are used to establish a protection criterion. A pilot protection scheme based on the standard deviation coefficient is proposed. The simulation results show that this method can reliably identify internal and external faults and has high sensitivity and selectivity. Moreover, this method is reliable for different types of faults and fault resistances. In addition, the proposed protection scheme can identify the type of fault in a short time window, requires a low sampling frequency, and does not require data synchronization.
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