Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548254
S. Sommerville, G. Taylor, M. Abbod
This paper considers the suitability of the standard DEGOV diesel generator governor model for use with reciprocating gas engine generators acting as primary frequency control units, within microgrids, due to the reduced capability of gas engines to accept step loads. The paper found that use of the standard DEGOV model would significantly overestimate the gas engines capability to accept step load, and an alternate model was developed using a gain scheduling controller, based on the generators existing loading. This model was found to be effective, but it was identified that the varying values of gain could lead to controller instability and tuning problems, and further investigation work in this area is necessary.
{"title":"Frequency Stability Considerations of Reciprocating Gas Engine Generators in Microgrids","authors":"S. Sommerville, G. Taylor, M. Abbod","doi":"10.1109/UPEC50034.2021.9548254","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548254","url":null,"abstract":"This paper considers the suitability of the standard DEGOV diesel generator governor model for use with reciprocating gas engine generators acting as primary frequency control units, within microgrids, due to the reduced capability of gas engines to accept step loads. The paper found that use of the standard DEGOV model would significantly overestimate the gas engines capability to accept step load, and an alternate model was developed using a gain scheduling controller, based on the generators existing loading. This model was found to be effective, but it was identified that the varying values of gain could lead to controller instability and tuning problems, and further investigation work in this area is necessary.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121813456","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548172
G. Kryonidis, Angelos I. Nousdilis, K. Pippi, T. Papadopoulos
Power smoothing (PS) techniques are employed to mitigate the network problems caused by the variable output power of non-dispatchable renewable energy sources (RESs). Keystone of these techniques is the use of a battery energy storage system (BESS) acting as an intermediate energy buffer to smooth the RES output power. Scope of this paper is to investigate the impact of the most well-established PS techniques on the long-term performance of BESSs focusing on capacity degradation. To this end, an accurate BESS aging model based on the rainflow cycle-counting algorithm is integrated to the examined PS techniques to estimate the cycle aging of the BESS. Furthermore, a parametric analysis with high-resolution RES measurements is performed to identify the most critical parameters that affect the PS capability and the BESS capacity degradation.
{"title":"Impact of Power Smoothing Techniques on the Long-Term Performance of Battery Energy Storage Systems","authors":"G. Kryonidis, Angelos I. Nousdilis, K. Pippi, T. Papadopoulos","doi":"10.1109/UPEC50034.2021.9548172","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548172","url":null,"abstract":"Power smoothing (PS) techniques are employed to mitigate the network problems caused by the variable output power of non-dispatchable renewable energy sources (RESs). Keystone of these techniques is the use of a battery energy storage system (BESS) acting as an intermediate energy buffer to smooth the RES output power. Scope of this paper is to investigate the impact of the most well-established PS techniques on the long-term performance of BESSs focusing on capacity degradation. To this end, an accurate BESS aging model based on the rainflow cycle-counting algorithm is integrated to the examined PS techniques to estimate the cycle aging of the BESS. Furthermore, a parametric analysis with high-resolution RES measurements is performed to identify the most critical parameters that affect the PS capability and the BESS capacity degradation.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123754530","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548245
Yevgeniy Kalinin, A. Chivenkov, Y. Vagapov, A. Anuchin
This paper discusses the processes of power loss development in the joint area of the laminated transformer core due to eddy currents produced by the normal magnetic flux. Normal magnetic flux is directed in perpendicular to the plane of the laminations and the dominating factor in the power loss formation in the joint area. The analytical approach was verified by a set of tests where two experimental setups have been employed to investigate power loss in the laminations under various conditions. The tests provided data on the power loss produced by the normal flux in relation to the lamination width and lamination overlap length. It was shown that the power loss in the joint area significantly depends on the lamination width and is independent of lamination overlap.
{"title":"Analysis and Experiential Verification of Power Loss in Joint Area of Laminated Transformer Core","authors":"Yevgeniy Kalinin, A. Chivenkov, Y. Vagapov, A. Anuchin","doi":"10.1109/UPEC50034.2021.9548245","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548245","url":null,"abstract":"This paper discusses the processes of power loss development in the joint area of the laminated transformer core due to eddy currents produced by the normal magnetic flux. Normal magnetic flux is directed in perpendicular to the plane of the laminations and the dominating factor in the power loss formation in the joint area. The analytical approach was verified by a set of tests where two experimental setups have been employed to investigate power loss in the laminations under various conditions. The tests provided data on the power loss produced by the normal flux in relation to the lamination width and lamination overlap length. It was shown that the power loss in the joint area significantly depends on the lamination width and is independent of lamination overlap.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125396616","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548207
Claudia Sheridan, M. Conlon
As Ireland moves towards decarbonization of electricity, Wind Power Plant Producers (WPP) face novel challenges and prospects. As of October 2018, WPP must partake in the Balancing Marketing where penalties will apply for active power variations. Power Plants in Ireland now also have new opportunities for receiving additional payments from system services. Co-location of Battery Energy Storage Systems (BESS) with a wind farm can be utilized to absorb additional power where curtailment may have been the only previous option, reduce the risk associated with balancing and offer grid stability as the levels of renewables increase. Using a large-scale Irish wind farm as a case study, the value of co-location of BESS under the existing Irish market regulations was examined. In this study, two separate revenue streams and modes of operation are investigated for one year. The use of BESS for balancing purposes and then for system services payments are considered in turn. The results show that while BESS can offer opportunities for WPP, the correct sizing and representation of degradation of BESS are critical due to the high capital cost of storage.
{"title":"A Techno-Economic Evaluation of Battery Energy Storage Systems co-located with Wind in the Irish Integrated Electricity Market","authors":"Claudia Sheridan, M. Conlon","doi":"10.1109/UPEC50034.2021.9548207","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548207","url":null,"abstract":"As Ireland moves towards decarbonization of electricity, Wind Power Plant Producers (WPP) face novel challenges and prospects. As of October 2018, WPP must partake in the Balancing Marketing where penalties will apply for active power variations. Power Plants in Ireland now also have new opportunities for receiving additional payments from system services. Co-location of Battery Energy Storage Systems (BESS) with a wind farm can be utilized to absorb additional power where curtailment may have been the only previous option, reduce the risk associated with balancing and offer grid stability as the levels of renewables increase. Using a large-scale Irish wind farm as a case study, the value of co-location of BESS under the existing Irish market regulations was examined. In this study, two separate revenue streams and modes of operation are investigated for one year. The use of BESS for balancing purposes and then for system services payments are considered in turn. The results show that while BESS can offer opportunities for WPP, the correct sizing and representation of degradation of BESS are critical due to the high capital cost of storage.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122146662","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548239
K. Makinde, G. Lacey
The considerable penetration of distributed generation (DG) in the distribution network (DN) invalidates the premises upon which distribution networks are designed. This penetration has resulted in a number of issues in the DN, the leading being voltage rise problem which occurs whenever generation is higher than the demand on the network thereby causing the power to flow in the reverse direction and subsequently leading to overvoltage. Many techniques discussed in the literature to mitigate this issue range from network reconfiguration to active management of the DN. This paper highlights the problem of overvoltage in DN with high penetration of DG and presents a technical overview of approaches to curtail the problem. IPSA software is then employed to model the effects of voltage control in low voltage distribution network.
{"title":"Over-voltage Problem in Distribution Network with DG: A Review of Mitigation Techniques","authors":"K. Makinde, G. Lacey","doi":"10.1109/UPEC50034.2021.9548239","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548239","url":null,"abstract":"The considerable penetration of distributed generation (DG) in the distribution network (DN) invalidates the premises upon which distribution networks are designed. This penetration has resulted in a number of issues in the DN, the leading being voltage rise problem which occurs whenever generation is higher than the demand on the network thereby causing the power to flow in the reverse direction and subsequently leading to overvoltage. Many techniques discussed in the literature to mitigate this issue range from network reconfiguration to active management of the DN. This paper highlights the problem of overvoltage in DN with high penetration of DG and presents a technical overview of approaches to curtail the problem. IPSA software is then employed to model the effects of voltage control in low voltage distribution network.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128412591","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548205
D. Mouton, Ndamulelo Mararakanye, B. Bekker
The addition of variable renewable energy (VRE) plants into the generation portfolio means that the power system has higher volatility, uncertainty, and variability. Therefore, there is an increased need for power system flexibility to account for this influx. Generation expansion planning entails strategizing an optimal long-term expansion plan for building new generation plants that satisfies economic and technical constraints. Concerns associated with VRE integration are evident in the case of the Namibian long-term expansion plan. The Namibian generation expansion plan makes use of two traditional adequacy planning techniques, namely loss of load probability (LOLP) and expected unsupplied energy (EUE), which are used for traditional generation plants where flexibility is already provided for. The problem with LOLP and EUE is that the only condition under which demand will not be met is when the demand exceeds the available capacity. The sole use of these metrics for generation expansion planning may be inadequate. Therefore, there is a need for flexibility assessment methods that can assess the flexibility of the Namibian power system to manage high variability. This paper reviews the different flexibility assessment methods available in literature studies and categorises the methods according to levels of computational complexity and data requirements. This paper finds that each level of flexibility assessment methods makes it possible to answer fundamental flexibility questions. Considering the findings, it is important to conduct all three levels of flexibility assessment methods to optimize flexibility.
{"title":"Assessment of Methods to Measure Power System Flexibility: A Review","authors":"D. Mouton, Ndamulelo Mararakanye, B. Bekker","doi":"10.1109/UPEC50034.2021.9548205","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548205","url":null,"abstract":"The addition of variable renewable energy (VRE) plants into the generation portfolio means that the power system has higher volatility, uncertainty, and variability. Therefore, there is an increased need for power system flexibility to account for this influx. Generation expansion planning entails strategizing an optimal long-term expansion plan for building new generation plants that satisfies economic and technical constraints. Concerns associated with VRE integration are evident in the case of the Namibian long-term expansion plan. The Namibian generation expansion plan makes use of two traditional adequacy planning techniques, namely loss of load probability (LOLP) and expected unsupplied energy (EUE), which are used for traditional generation plants where flexibility is already provided for. The problem with LOLP and EUE is that the only condition under which demand will not be met is when the demand exceeds the available capacity. The sole use of these metrics for generation expansion planning may be inadequate. Therefore, there is a need for flexibility assessment methods that can assess the flexibility of the Namibian power system to manage high variability. This paper reviews the different flexibility assessment methods available in literature studies and categorises the methods according to levels of computational complexity and data requirements. This paper finds that each level of flexibility assessment methods makes it possible to answer fundamental flexibility questions. Considering the findings, it is important to conduct all three levels of flexibility assessment methods to optimize flexibility.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"191 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114725521","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In recent years, there have been situations in which the zero-sequence protection of the transformer has been incorrectly operated due to the converter transformer energizing or fault recovery. For converter transformers, maloperation may also occur. However, there is almost no theoretical research on the zero-mode inrush currents of converter transformers. This paper studies the characteristics of the zero-mode inrush currents of the converter transformers, including the relationship between the amplitude and attenuation characteristics of the zero-mode inrush currents of converter transformers, and their relationship with the system resistance, remanence, and closing angle. First, based on the T-type equivalent circuit of the transformer, the equivalent circuit of the zero-mode inrush current of each transformer is obtained. On this basis, the amplitude relationship of the zero-mode inrush currents of different converter transformers is obtained: the zero-mode inrush current of the energizing pole YY transformer becomes larger than the YD transformer, the energized pole YD becomes greater than the YY transformer, and the YY transformer zero-mode inrush current rises from 0. It is also analyzed that the sympathetic interaction will make the attenuation of the converter transformer zero-mode inrush current slower. The system resistance mainly affects the initial attenuation speed, and the later attenuation speed is mainly determined by the converter transformer leakage reactance. Finally, PSCAD modeling and simulation are carried out to verify the accuracy of the theoretical analysis.
{"title":"Analysis of zero-mode inrush current characteristics of converter transformers","authors":"Zhichang Liu, Xin Yin, Yuanlin Pan, Wei Xi, Xianggen Yin, Binyan Liu","doi":"10.1109/UPEC50034.2021.9548277","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548277","url":null,"abstract":"In recent years, there have been situations in which the zero-sequence protection of the transformer has been incorrectly operated due to the converter transformer energizing or fault recovery. For converter transformers, maloperation may also occur. However, there is almost no theoretical research on the zero-mode inrush currents of converter transformers. This paper studies the characteristics of the zero-mode inrush currents of the converter transformers, including the relationship between the amplitude and attenuation characteristics of the zero-mode inrush currents of converter transformers, and their relationship with the system resistance, remanence, and closing angle. First, based on the T-type equivalent circuit of the transformer, the equivalent circuit of the zero-mode inrush current of each transformer is obtained. On this basis, the amplitude relationship of the zero-mode inrush currents of different converter transformers is obtained: the zero-mode inrush current of the energizing pole YY transformer becomes larger than the YD transformer, the energized pole YD becomes greater than the YY transformer, and the YY transformer zero-mode inrush current rises from 0. It is also analyzed that the sympathetic interaction will make the attenuation of the converter transformer zero-mode inrush current slower. The system resistance mainly affects the initial attenuation speed, and the later attenuation speed is mainly determined by the converter transformer leakage reactance. Finally, PSCAD modeling and simulation are carried out to verify the accuracy of the theoretical analysis.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131920498","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548164
N. Azizi, H. M. Cheshmehbeigi, K. Rouzbehi, Hassan NOURI
High voltage direct current (HVDC) breaker is among the essential components of HVDC grids. Currently, DC circuit breakers (DCCBs) of HVDC grids require relatively large DC reactors to limit the rate of increase of fault current. However, DC reactors have destructive effects on the multi-terminal HVDC (MT-HVDC) grid dynamic stability, and in such a system, despite the variety of controllers, the system dynamics are highly sensitive to the operating point. This paper proposes a modification to be applied to the droop control of Multi-terminal HVDC (MT-HVDC) grids for stabilizing the DC voltage and power variations in case of transient events by the introduction of a Dead Band Direct Current Power System Stabilizer (DBDC-PSS). Also, this paper presents the classification of MT-HVDC grid dynamic behavior in different scenarios including without DC-PSS, conventional DC-PSS, and DBDC-PSS. All simulations and analytical studies are conducted on Cigré DCS3 test HVDC grid in MATLAB/Simulink.
{"title":"Voltage Stability Improvement in Multi-Terminal HVDC grids: A Case Study of Cigré B4 HVDC Test Grid","authors":"N. Azizi, H. M. Cheshmehbeigi, K. Rouzbehi, Hassan NOURI","doi":"10.1109/UPEC50034.2021.9548164","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548164","url":null,"abstract":"High voltage direct current (HVDC) breaker is among the essential components of HVDC grids. Currently, DC circuit breakers (DCCBs) of HVDC grids require relatively large DC reactors to limit the rate of increase of fault current. However, DC reactors have destructive effects on the multi-terminal HVDC (MT-HVDC) grid dynamic stability, and in such a system, despite the variety of controllers, the system dynamics are highly sensitive to the operating point. This paper proposes a modification to be applied to the droop control of Multi-terminal HVDC (MT-HVDC) grids for stabilizing the DC voltage and power variations in case of transient events by the introduction of a Dead Band Direct Current Power System Stabilizer (DBDC-PSS). Also, this paper presents the classification of MT-HVDC grid dynamic behavior in different scenarios including without DC-PSS, conventional DC-PSS, and DBDC-PSS. All simulations and analytical studies are conducted on Cigré DCS3 test HVDC grid in MATLAB/Simulink.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132332285","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548253
O. G. Olasunkanmi, Zhida Deng, G. Todeschini
The subject of this work is the development of a load flow model for the Nigerian 330 kV transmission system. The model has been developed in DIgSILENT PowerFactory based on data provided by the Nigerian Electricity system operator (NESO). Two scenarios (summer and winter) were considered: for each scenario, load data, generator data, and transmission line parameters were used as inputs to the model. The voltage profiles resulting from the load flow were compared with the original data, and some discrepancies were found. Assumptions and modifications were made to achieve load flow results that were closer to the system data. The results show that in summer and winter, power generated was 4804.10 MW and 4394.41 MW, respectively. The bus voltages were within the voltage magnitude of 0.85 pu and 1.05 pu, according to the local grid code. The model documented in this paper will be used as a baseline for reliability and stability studies. This research aims to identify potential reinforcements to the 330 kV Nigerian transmission system to meet future electricity demand.
{"title":"Load Flow Analysis of the Nigerian Transmission Grid Using DIgSILENT PowerFactory","authors":"O. G. Olasunkanmi, Zhida Deng, G. Todeschini","doi":"10.1109/UPEC50034.2021.9548253","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548253","url":null,"abstract":"The subject of this work is the development of a load flow model for the Nigerian 330 kV transmission system. The model has been developed in DIgSILENT PowerFactory based on data provided by the Nigerian Electricity system operator (NESO). Two scenarios (summer and winter) were considered: for each scenario, load data, generator data, and transmission line parameters were used as inputs to the model. The voltage profiles resulting from the load flow were compared with the original data, and some discrepancies were found. Assumptions and modifications were made to achieve load flow results that were closer to the system data. The results show that in summer and winter, power generated was 4804.10 MW and 4394.41 MW, respectively. The bus voltages were within the voltage magnitude of 0.85 pu and 1.05 pu, according to the local grid code. The model documented in this paper will be used as a baseline for reliability and stability studies. This research aims to identify potential reinforcements to the 330 kV Nigerian transmission system to meet future electricity demand.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131062318","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-08-31DOI: 10.1109/UPEC50034.2021.9548238
Héricles Eduardo Oliveira Farias, Camilo Alberto Sepulveda Rangel, L. Canha, Leonardo Weber Stringini, T. A. Silva Santana, Zeno Luiz Iensen Nadal
This paper presents a methodology for battery energy storage systems (BESS) management considering the concept of transactive energy. Transactive energy is defined as the economic and control technique used for energy management that allows the dynamic balance of supply and demand across the electrical system. In a transactive energy market, the consumer can produce energy and inject it into the grid, becoming a prosumer. Also, it is possible to have the presence of private aggregators. Aggregators have large energy production capacity and can negotiate this energy with the grid. The system is composed by two private aggregators, the consumers, and the distribution system operator (DSO). The aggregators are assigned to supply a specific number of consumers defined in the contractual demand with the DSO, and the DSO is responsible for serving the rest of the system. Both aggregators and the DSO have distributed energy resources (DERs), such as energy storage and/or photovoltaic generation. A neural network based on group method of data handling (GMDH) is used for forecasting the grid demand, energy prices and solar generation for the day-ahead operation. The BESS reserve for the day-ahead is optimized based on prediction model. The methodology is validated in a 33-bus distribution network simulated on software OpenDSS. The curve profiles are taken from real data of the Canadian distribution system.
{"title":"Battery energy storage systems management in a day-ahead market scenario with transactive energy and private aggregators","authors":"Héricles Eduardo Oliveira Farias, Camilo Alberto Sepulveda Rangel, L. Canha, Leonardo Weber Stringini, T. A. Silva Santana, Zeno Luiz Iensen Nadal","doi":"10.1109/UPEC50034.2021.9548238","DOIUrl":"https://doi.org/10.1109/UPEC50034.2021.9548238","url":null,"abstract":"This paper presents a methodology for battery energy storage systems (BESS) management considering the concept of transactive energy. Transactive energy is defined as the economic and control technique used for energy management that allows the dynamic balance of supply and demand across the electrical system. In a transactive energy market, the consumer can produce energy and inject it into the grid, becoming a prosumer. Also, it is possible to have the presence of private aggregators. Aggregators have large energy production capacity and can negotiate this energy with the grid. The system is composed by two private aggregators, the consumers, and the distribution system operator (DSO). The aggregators are assigned to supply a specific number of consumers defined in the contractual demand with the DSO, and the DSO is responsible for serving the rest of the system. Both aggregators and the DSO have distributed energy resources (DERs), such as energy storage and/or photovoltaic generation. A neural network based on group method of data handling (GMDH) is used for forecasting the grid demand, energy prices and solar generation for the day-ahead operation. The BESS reserve for the day-ahead is optimized based on prediction model. The methodology is validated in a 33-bus distribution network simulated on software OpenDSS. The curve profiles are taken from real data of the Canadian distribution system.","PeriodicalId":325389,"journal":{"name":"2021 56th International Universities Power Engineering Conference (UPEC)","volume":"67 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128858139","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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