Pub Date : 2019-05-01DOI: 10.1109/ICPS.2019.8733362
Philip Chow, M. Walker
This paper discusses risk mitigation strategies for emergency power upgrades in critical facilities, such as hospitals and data centers. Larger facilities and campuses, typically have complex emergency power systems, which rely on multiple standby generators, control systems for paralleling and automatic transfer sequences, switchgear and medium voltage power distribution systems. Integration amongst components is essential in ensuring reliable operation of the emergency power system. Given the critical nature of the loads supported by emergency power systems, downtime cannot be tolerated. There are a number of risk mitigation strategies that can be undertaken to minimize the operational risk associated with equipment upgrade projects. This paper will review successful strategies from two separate projects that involved completely upgrading emergency power systems.
{"title":"Risk Mitigation Strategies for Emergency Power Upgrades in Critical Facilities","authors":"Philip Chow, M. Walker","doi":"10.1109/ICPS.2019.8733362","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733362","url":null,"abstract":"This paper discusses risk mitigation strategies for emergency power upgrades in critical facilities, such as hospitals and data centers. Larger facilities and campuses, typically have complex emergency power systems, which rely on multiple standby generators, control systems for paralleling and automatic transfer sequences, switchgear and medium voltage power distribution systems. Integration amongst components is essential in ensuring reliable operation of the emergency power system. Given the critical nature of the loads supported by emergency power systems, downtime cannot be tolerated. There are a number of risk mitigation strategies that can be undertaken to minimize the operational risk associated with equipment upgrade projects. This paper will review successful strategies from two separate projects that involved completely upgrading emergency power systems.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132323165","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}
With the rapidly increased penetration of renewable generations, incentive-based demand side management (DSM) shows great value on alleviating the uncertainty and providing flexibility for microgrid. However, how to price those demand resources becomes one of the most significant challenges for promoting incentive-based DSM under microgrid environments. In this paper, a flexible demand resource pricing scheme is proposed. Instead of using utility function of end users like most existing literatures, the economic benefit of flexible demand resources is evaluated by the operation performance enhancement of microgrid and correspondingly the resource is priced based on a benefit sharing approach. An iteration-based chance-constrained method is established to calculate the economic benefit and shared compensation for demand resource providers. Meanwhile, the financial risks for microgrid operator due to uncertain factors are mitigated by the chance-constrained criterion. The proposed scheme is examined by an experimental microgrid to illustrate its effectiveness.
{"title":"Flexible Demand Resource Pricing Scheme: A Stochastic Benefit-Sharing Approach","authors":"Zhaohao Ding, Fengtian Zhu, Yajing Wang, Ying Lu, Lizi Zhang","doi":"10.1109/ICPS.2019.8733337","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733337","url":null,"abstract":"With the rapidly increased penetration of renewable generations, incentive-based demand side management (DSM) shows great value on alleviating the uncertainty and providing flexibility for microgrid. However, how to price those demand resources becomes one of the most significant challenges for promoting incentive-based DSM under microgrid environments. In this paper, a flexible demand resource pricing scheme is proposed. Instead of using utility function of end users like most existing literatures, the economic benefit of flexible demand resources is evaluated by the operation performance enhancement of microgrid and correspondingly the resource is priced based on a benefit sharing approach. An iteration-based chance-constrained method is established to calculate the economic benefit and shared compensation for demand resource providers. Meanwhile, the financial risks for microgrid operator due to uncertain factors are mitigated by the chance-constrained criterion. The proposed scheme is examined by an experimental microgrid to illustrate its effectiveness.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129830992","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733323
F. B. Ajaei, J. Mohammadi, G. Stevens, E. Akhavan
The hybrid microgrid is attracting great attention in recent years as it combines the main advantages of the alternating current (AC) and direct current (DC) microgrids. It is one of the best candidates to support a net-zero energy community. Thus, this paper investigates and compares different hybrid AC/DC microgrid configurations that are suitable for a net-zero energy community. Four different configurations are compared with each other in terms of their impacts on the overall system reliability, expandability, load shedding requirements, power sharing issues, net-zero energy capability, number of the required interface converters, and the requirement of costly medium-voltage components. The results of the investigations indicate that the best results are achieved when each building is enabled to supply its critical loads using an independent AC microgrid that is interfaced to the DC microgrid through a dedicated interface converter.
{"title":"Hybrid AC/DC Microgrid Configurations for a Net-Zero Energy Community","authors":"F. B. Ajaei, J. Mohammadi, G. Stevens, E. Akhavan","doi":"10.1109/ICPS.2019.8733323","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733323","url":null,"abstract":"The hybrid microgrid is attracting great attention in recent years as it combines the main advantages of the alternating current (AC) and direct current (DC) microgrids. It is one of the best candidates to support a net-zero energy community. Thus, this paper investigates and compares different hybrid AC/DC microgrid configurations that are suitable for a net-zero energy community. Four different configurations are compared with each other in terms of their impacts on the overall system reliability, expandability, load shedding requirements, power sharing issues, net-zero energy capability, number of the required interface converters, and the requirement of costly medium-voltage components. The results of the investigations indicate that the best results are achieved when each building is enabled to supply its critical loads using an independent AC microgrid that is interfaced to the DC microgrid through a dedicated interface converter.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133612959","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733382
Yuan-Kang Wu, Shih-Ming Chang, P. Mandal
In recent years, the integration of wind power generation, especially for offshore wind power, has increased rapidly. Therefore, the requirements of grid codes on wind power integration becomes a major factor in the power system reliability. This paper compares and summarizes the grid codes and the corresponding works about wind power integration around the world. The grid codes issued by Denmark, Ireland, UK, Germany, Spain, China, US, Canada, and other representative countries have been studied. The main requirements of the grid codes include reactive power, frequency regulation, fault ride through, and power quality. Additionally, several grid codes also address the requirements on communication, ramp rate, and offshore wind power plants (WPP). Finally, this paper provides the information about the future trend of grid code requirements on offshore wind power integration, which helps the grid operators ensure a safe operation for high wind-power penetration.
{"title":"Grid-Connected Wind Power Plants: A Survey on the Integration Requirements in Modern Grid Codes","authors":"Yuan-Kang Wu, Shih-Ming Chang, P. Mandal","doi":"10.1109/ICPS.2019.8733382","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733382","url":null,"abstract":"In recent years, the integration of wind power generation, especially for offshore wind power, has increased rapidly. Therefore, the requirements of grid codes on wind power integration becomes a major factor in the power system reliability. This paper compares and summarizes the grid codes and the corresponding works about wind power integration around the world. The grid codes issued by Denmark, Ireland, UK, Germany, Spain, China, US, Canada, and other representative countries have been studied. The main requirements of the grid codes include reactive power, frequency regulation, fault ride through, and power quality. Additionally, several grid codes also address the requirements on communication, ramp rate, and offshore wind power plants (WPP). Finally, this paper provides the information about the future trend of grid code requirements on offshore wind power integration, which helps the grid operators ensure a safe operation for high wind-power penetration.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"3 23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126184547","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733353
Sidun Fang, Yan Xu, Zhengmao Li
Currently, lots of research have revealed the great potentials of the land-based carbon capture and storage (CCS) system on the control of the greenhouse gas (GHG) emission. But when it comes to the shipboard applications, the CCS integration becomes rather complicated since very limited operating conditions onboard, especially for the shortage of power supply. Nowadays, the all-electric ship (AES), which uses electricity to meet both the propulsion and service loads, has become a trend for future ship designing due to higher efficiency and flexibility, as well as providing a better platform for CCS integration and paving a new way for maritime GHG emission control. To address the power shortage issue led by the CCS integration, this paper first incorporates the demand-side management on the propulsion load and a corresponding joint generation and demand-side management model is proposed. The mathematical model is formulated as a bi-level optimization after certain constraint decomposition and solved by the column and constraint generation algorithm. Extensive simulations demonstrate that, the proposed method is able to relieve the power shortage issue of shipboard CCS, and the corresponding carbon capture level increases from 86% to 93%.
{"title":"Joint Generation and Demand-side Management for Shipboard Carbon Capture and Storage System","authors":"Sidun Fang, Yan Xu, Zhengmao Li","doi":"10.1109/ICPS.2019.8733353","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733353","url":null,"abstract":"Currently, lots of research have revealed the great potentials of the land-based carbon capture and storage (CCS) system on the control of the greenhouse gas (GHG) emission. But when it comes to the shipboard applications, the CCS integration becomes rather complicated since very limited operating conditions onboard, especially for the shortage of power supply. Nowadays, the all-electric ship (AES), which uses electricity to meet both the propulsion and service loads, has become a trend for future ship designing due to higher efficiency and flexibility, as well as providing a better platform for CCS integration and paving a new way for maritime GHG emission control. To address the power shortage issue led by the CCS integration, this paper first incorporates the demand-side management on the propulsion load and a corresponding joint generation and demand-side management model is proposed. The mathematical model is formulated as a bi-level optimization after certain constraint decomposition and solved by the column and constraint generation algorithm. Extensive simulations demonstrate that, the proposed method is able to relieve the power shortage issue of shipboard CCS, and the corresponding carbon capture level increases from 86% to 93%.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114617389","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733328
Ming-Tse Kuo, Ming-Chang Tsou, Shiue‐Der Lu
A novel over-current protection methodology applied for flyback converters is proposed, with advantages of getting immune to input voltage variation and inductance deviation from production-line manufacturing and thus accurate over-current-protection (OCP) is available. Experimental results guarantee highly significant improvement based on OCP variation less than 0.733% under universal line voltage conditions. Moreover, additional components are unnecessary in a real board, bringing no burden in circuit design. The aforementioned advantages of the target features have been analyzed in detail through conscientious simulations and the feasibilities are verified depending on prototypical circuits.
{"title":"Novel Over-Current Protection (OCP) Methodology Applied for Flyback Converters to Improve Accuracy of OCP of Industrial Productions","authors":"Ming-Tse Kuo, Ming-Chang Tsou, Shiue‐Der Lu","doi":"10.1109/ICPS.2019.8733328","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733328","url":null,"abstract":"A novel over-current protection methodology applied for flyback converters is proposed, with advantages of getting immune to input voltage variation and inductance deviation from production-line manufacturing and thus accurate over-current-protection (OCP) is available. Experimental results guarantee highly significant improvement based on OCP variation less than 0.733% under universal line voltage conditions. Moreover, additional components are unnecessary in a real board, bringing no burden in circuit design. The aforementioned advantages of the target features have been analyzed in detail through conscientious simulations and the feasibilities are verified depending on prototypical circuits.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123038080","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733322
D. Kang, Hyuntae Kim, Sungyun Choi
As cyber assets have become essential components in the operation of bulk electric power systems, cyberattacks can make massive impacts on physical systems, eventually causing severe economic losses. The paper presents methods to measure the economic impacts of cyberattacks in various sectors of bulk electric systems such as the energy management system (EMS), generations systems, and transmission systems. This paper explains the interaction mechanisms of how cyber threats can affect physical electric systems and, then, presents how to measure economic losses incurred by those cyber threats. These economic losses include power outage costs, transmission loss, and operating loss. The paper describes possible cyberattack scenarios in the three essential electric power systems, as well as simulation methods to measure resultant economic losses.
{"title":"Methodology for Quantifying the Economic Impact of Cyberattacks on Bulk Electric Systems","authors":"D. Kang, Hyuntae Kim, Sungyun Choi","doi":"10.1109/ICPS.2019.8733322","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733322","url":null,"abstract":"As cyber assets have become essential components in the operation of bulk electric power systems, cyberattacks can make massive impacts on physical systems, eventually causing severe economic losses. The paper presents methods to measure the economic impacts of cyberattacks in various sectors of bulk electric systems such as the energy management system (EMS), generations systems, and transmission systems. This paper explains the interaction mechanisms of how cyber threats can affect physical electric systems and, then, presents how to measure economic losses incurred by those cyber threats. These economic losses include power outage costs, transmission loss, and operating loss. The paper describes possible cyberattack scenarios in the three essential electric power systems, as well as simulation methods to measure resultant economic losses.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"94 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114944273","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733343
Zhe Li, Chengfu Wang, Ying Ding, Ming Yang, Wenli Zhu
Owing to higher energy supply efficiency and operational flexibility, integrated energy system (IES), including power, heating and gas systems, will be the primary form of energy supply in the future. However, with the increase of large-scale stochastic wind power integrated, the IES operation will face significant challenge as same as traditional power system. In view of the above problems, considering the probability distribution characteristics of wind power, a conditional value-at-risk (CVaR) based probability-interval method is proposed to describe the uncertain wind power in this paper. Then, besides traditional facilities, electricity storage system (ESS) is introduced to improve the flexibility of IES. Furthermore, a planning model is established based on minimizing the total cost including investment, operation, CVaR cost and unserved energy cost. Finally, an IEEE14-NGS14 system is constructed and its planning model is solved by GAMS/CPLEX. The numerical results illustrate the correctness and effectiveness of the proposed method.
{"title":"Probability-Interval based Optimal Planning of Integrated Energy System with Uncertain Wind Power","authors":"Zhe Li, Chengfu Wang, Ying Ding, Ming Yang, Wenli Zhu","doi":"10.1109/ICPS.2019.8733343","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733343","url":null,"abstract":"Owing to higher energy supply efficiency and operational flexibility, integrated energy system (IES), including power, heating and gas systems, will be the primary form of energy supply in the future. However, with the increase of large-scale stochastic wind power integrated, the IES operation will face significant challenge as same as traditional power system. In view of the above problems, considering the probability distribution characteristics of wind power, a conditional value-at-risk (CVaR) based probability-interval method is proposed to describe the uncertain wind power in this paper. Then, besides traditional facilities, electricity storage system (ESS) is introduced to improve the flexibility of IES. Furthermore, a planning model is established based on minimizing the total cost including investment, operation, CVaR cost and unserved energy cost. Finally, an IEEE14-NGS14 system is constructed and its planning model is solved by GAMS/CPLEX. The numerical results illustrate the correctness and effectiveness of the proposed method.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"90 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127048045","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733344
Divya T. Vedullapalli, R. Hadidi, Bill Schroeder
The objective of this project is to develop a load forecasting technique and demand management algorithm for a building to schedule battery and Heating Ventilation Air Conditioning system (HVAC) using the Model Predictive Control (MPC). Behind-the-meter energy storage is used for modifying the load shape and minimizing the demand charge of a building. Thermal mass of the building can also be utilized to store the heat/cool energy and HVAC is scheduled to minimize power consumption during peak times. This paper optimizes the battery schedule to minimize the monthly electricity bill. The load profile has to be forecasted and this algorithm uses a two-part forecaster where a deterministic part uses exponentially weighted moving average (EWMA) model accounting for longer term trends and a second order regression model (AR2) accounting for the short term variations. A novel mathematical model has been proposed for calculating HVAC power consumption with a given thermostat schedule. Greater savings can be realized by augmenting this algorithm with HVAC scheduling and authors are working on it minimize HVAC power consumption during peak hours without causing thermal discomfort to the residents of the building.
{"title":"Optimal Demand Response in a building by Battery and HVAC scheduling using Model Predictive Control","authors":"Divya T. Vedullapalli, R. Hadidi, Bill Schroeder","doi":"10.1109/ICPS.2019.8733344","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733344","url":null,"abstract":"The objective of this project is to develop a load forecasting technique and demand management algorithm for a building to schedule battery and Heating Ventilation Air Conditioning system (HVAC) using the Model Predictive Control (MPC). Behind-the-meter energy storage is used for modifying the load shape and minimizing the demand charge of a building. Thermal mass of the building can also be utilized to store the heat/cool energy and HVAC is scheduled to minimize power consumption during peak times. This paper optimizes the battery schedule to minimize the monthly electricity bill. The load profile has to be forecasted and this algorithm uses a two-part forecaster where a deterministic part uses exponentially weighted moving average (EWMA) model accounting for longer term trends and a second order regression model (AR2) accounting for the short term variations. A novel mathematical model has been proposed for calculating HVAC power consumption with a given thermostat schedule. Greater savings can be realized by augmenting this algorithm with HVAC scheduling and authors are working on it minimize HVAC power consumption during peak hours without causing thermal discomfort to the residents of the building.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"70 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126804217","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 : 2019-05-01DOI: 10.1109/ICPS.2019.8733358
Adam Mate, E. C. Sanchez
Quick and reliable power system restoration is critically important after natural disasters or other sudden threats, such as cyber-attacks. Leveraging renewable resources in system restoration shortens recovery times, resulting in prevented life-loss and avoided economic-loss, and improves the resilience of the entire grid. However, it is not a common practice today; the inherent variability of these resources represents a challenge for a streamlined restoration process. This paper presents a prioritized method - starting with renewable generator units then lowering priority to conventional units - to plan the operational schedule of a power system during the restoration process. The goal is to achieve a well balanced system in the presence of significant renewable penetration. Validation and benchmarking experiments were performed on a customized version of the RTS-GMLC test system using six months out of year-long data, tested through hourly simulations. After evaluating the performance and computational costs, this method proved faster than common approaches: a MILP Unit Commitment algorithm, widely used today, and an “enable-and-try” algorithm. In summary, herein a more convenient method is provided to be utilized during time-sensitive restoration, as an online operation-planning aid.
{"title":"Rapid Method for Generation Prioritization during System Restoration with Renewable Resources","authors":"Adam Mate, E. C. Sanchez","doi":"10.1109/ICPS.2019.8733358","DOIUrl":"https://doi.org/10.1109/ICPS.2019.8733358","url":null,"abstract":"Quick and reliable power system restoration is critically important after natural disasters or other sudden threats, such as cyber-attacks. Leveraging renewable resources in system restoration shortens recovery times, resulting in prevented life-loss and avoided economic-loss, and improves the resilience of the entire grid. However, it is not a common practice today; the inherent variability of these resources represents a challenge for a streamlined restoration process. This paper presents a prioritized method - starting with renewable generator units then lowering priority to conventional units - to plan the operational schedule of a power system during the restoration process. The goal is to achieve a well balanced system in the presence of significant renewable penetration. Validation and benchmarking experiments were performed on a customized version of the RTS-GMLC test system using six months out of year-long data, tested through hourly simulations. After evaluating the performance and computational costs, this method proved faster than common approaches: a MILP Unit Commitment algorithm, widely used today, and an “enable-and-try” algorithm. In summary, herein a more convenient method is provided to be utilized during time-sensitive restoration, as an online operation-planning aid.","PeriodicalId":160476,"journal":{"name":"2019 IEEE/IAS 55th Industrial and Commercial Power Systems Technical Conference (I&CPS)","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129927668","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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