Pub Date : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917052
Chengcheng Shao, Ke Li, Tao Qian, Xifan Wang, M. Shahidehpour
The increasing electric vehicles (EVs) imposes great challenges on the coordination between the power distribution network (PDN) and transportation network (TN). This paper proposes the generalized user equilibrium (GUE) method to manage their interactions. First, the concept of GUE is proposed to describe the steady-state distribution of the traffic flow as extension of user equilibrium (UE) which could no longer exist due to the influence of PDN operation on TN. Second, the GUE model is established via which the operation of PDN and TN is coordinated with traffic assigned and power generation scheduled simultaneously. Finally, an efficient solution algorithm is proposed by decomposing the primal problem into a master problem and a series of feasible and optimal path generation sub-problems for individual origin-destination (O-D) pairs. The effectiveness of the proposed method has been verified via case studies based on a real-world city TN. The results demonstrate the necessity of GUE and its potential in improving the operation of coupled power-traffic networks.
{"title":"Generalized User Equilibrium for Coordinated Operation of Power-Traffic Networks","authors":"Chengcheng Shao, Ke Li, Tao Qian, Xifan Wang, M. Shahidehpour","doi":"10.1109/PESGM48719.2022.9917052","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917052","url":null,"abstract":"The increasing electric vehicles (EVs) imposes great challenges on the coordination between the power distribution network (PDN) and transportation network (TN). This paper proposes the generalized user equilibrium (GUE) method to manage their interactions. First, the concept of GUE is proposed to describe the steady-state distribution of the traffic flow as extension of user equilibrium (UE) which could no longer exist due to the influence of PDN operation on TN. Second, the GUE model is established via which the operation of PDN and TN is coordinated with traffic assigned and power generation scheduled simultaneously. Finally, an efficient solution algorithm is proposed by decomposing the primal problem into a master problem and a series of feasible and optimal path generation sub-problems for individual origin-destination (O-D) pairs. The effectiveness of the proposed method has been verified via case studies based on a real-world city TN. The results demonstrate the necessity of GUE and its potential in improving the operation of coupled power-traffic networks.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114699838","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917134
Qinghan Sun, Qun Chen, Ke-Lun He
Decentralized dispatch of distributed energy systems connected with distribution networks(DN) and district heating systems(DHS) has drawn great attention recently. However, the heat transfer between fluids with different temperatures in the heating system usually lacks proper consideration. In this work, the delay and loss characteristics of the pipelines and the heat transfer at the heat exchange stations in the DHS are thoroughly modelled. A fully decentralized solution based on Alternating Direction Method of Multipliers(ADMM) is used to solve the dispatch problem. Case study on a integrated system composed of 17 agents validates the importance of a comprehensive DHS model and the effectiveness of the proposed method.
{"title":"Fully Decentralized Dispatch of Integrated Power Distribution and Heating Systems Considering Nonlinear Heat Transfer Processes","authors":"Qinghan Sun, Qun Chen, Ke-Lun He","doi":"10.1109/PESGM48719.2022.9917134","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917134","url":null,"abstract":"Decentralized dispatch of distributed energy systems connected with distribution networks(DN) and district heating systems(DHS) has drawn great attention recently. However, the heat transfer between fluids with different temperatures in the heating system usually lacks proper consideration. In this work, the delay and loss characteristics of the pipelines and the heat transfer at the heat exchange stations in the DHS are thoroughly modelled. A fully decentralized solution based on Alternating Direction Method of Multipliers(ADMM) is used to solve the dispatch problem. Case study on a integrated system composed of 17 agents validates the importance of a comprehensive DHS model and the effectiveness of the proposed method.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"171 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116004114","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9916768
H. Shuai, F. Li, Héctor Pulgar-Painemal, Yaosuo Xue
This letter investigates a Branching Dueling Q-Network (BDQ) based online operation strategy for a microgrid with distributed battery energy storage systems (BESSs) operating under uncertainties. The developed deep reinforcement learning (DRL) based microgrid online optimization strategy can achieve a linear increase in the number of neural network outputs with the number of distributed BESSs, which overcomes the curse of dimensionality caused by the charge and discharge decisions of multiple BESSs. Numerical simulations validate the effectiveness of the proposed method.
{"title":"Branching Dueling Q-Network-Based Online Scheduling of a Microgrid With Distributed Energy Storage Systems","authors":"H. Shuai, F. Li, Héctor Pulgar-Painemal, Yaosuo Xue","doi":"10.1109/PESGM48719.2022.9916768","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9916768","url":null,"abstract":"This letter investigates a Branching Dueling Q-Network (BDQ) based online operation strategy for a microgrid with distributed battery energy storage systems (BESSs) operating under uncertainties. The developed deep reinforcement learning (DRL) based microgrid online optimization strategy can achieve a linear increase in the number of neural network outputs with the number of distributed BESSs, which overcomes the curse of dimensionality caused by the charge and discharge decisions of multiple BESSs. Numerical simulations validate the effectiveness of the proposed method.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"51 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116011786","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917172
Oscar S. Acosta, P. Mandal, Eric Galvan, T. Senjyu
This paper presents a thorough technical analysis by introducing grid-connected solar photovoltaic (PV) systems to meet the electrical energy demand of HVAC systems in residential housing units spanning the U.S. The proposed model utilizes DOE backed survey data and solar irradiance levels to size PV systems to support electrical load requirements for air conditioning and heating components in housing within all major U.S. climate regions. To perform the analysis, average annual load data provided by energy information administration (EIA) surveys based on NREL benchmark simulation house parameters are calculated against solar radiation data to determine PV array sizing. The calculated PV systems were tested by simulating their operation to estimate an average annual production profile that was compared to the total average annual household load in order to determine overall potential annual load reduction.
{"title":"Integrated Photovoltaic (PV) System for Modeling Residential HVAC Loads – Technical Analysis","authors":"Oscar S. Acosta, P. Mandal, Eric Galvan, T. Senjyu","doi":"10.1109/PESGM48719.2022.9917172","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917172","url":null,"abstract":"This paper presents a thorough technical analysis by introducing grid-connected solar photovoltaic (PV) systems to meet the electrical energy demand of HVAC systems in residential housing units spanning the U.S. The proposed model utilizes DOE backed survey data and solar irradiance levels to size PV systems to support electrical load requirements for air conditioning and heating components in housing within all major U.S. climate regions. To perform the analysis, average annual load data provided by energy information administration (EIA) surveys based on NREL benchmark simulation house parameters are calculated against solar radiation data to determine PV array sizing. The calculated PV systems were tested by simulating their operation to estimate an average annual production profile that was compared to the total average annual household load in order to determine overall potential annual load reduction.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123538727","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917041
M. R. Feizi, Abdulraheem H. Alobaidi, M. Khodayar
The increase in the generation capacity of the variable renewable resources and electricity demand introduces new operational challenges to the unbalanced three-phase distribution networks. This paper addresses the uncertainty associated with the ramping of net demand using a data-driven approach. A continuous-time optimization problem is reformulated to a linear programming problem using Bernstein polynomials. A distributionally robust optimization problem is formulated to capture the worst-case probability distribution of the net demand, which includes the demand and the PV generation. The solution to the distributionally robust operation of the unbalanced distribution network is compared to that of the stochastic programming problem in which the uncertainty associated with the net demand ramp is captured using scenarios. The developed formulated problem is validated using a modified IEEE 13-bus unbalanced distribution system. The impact of ramp limits of the main feeder on the expected operation cost of the distribution network is investigated.
{"title":"Data-Driven Distributionally Robust Operation of Distribution Networks with Ramping Flexibility","authors":"M. R. Feizi, Abdulraheem H. Alobaidi, M. Khodayar","doi":"10.1109/PESGM48719.2022.9917041","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917041","url":null,"abstract":"The increase in the generation capacity of the variable renewable resources and electricity demand introduces new operational challenges to the unbalanced three-phase distribution networks. This paper addresses the uncertainty associated with the ramping of net demand using a data-driven approach. A continuous-time optimization problem is reformulated to a linear programming problem using Bernstein polynomials. A distributionally robust optimization problem is formulated to capture the worst-case probability distribution of the net demand, which includes the demand and the PV generation. The solution to the distributionally robust operation of the unbalanced distribution network is compared to that of the stochastic programming problem in which the uncertainty associated with the net demand ramp is captured using scenarios. The developed formulated problem is validated using a modified IEEE 13-bus unbalanced distribution system. The impact of ramp limits of the main feeder on the expected operation cost of the distribution network is investigated.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116802317","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917223
Janne Seppänen, M. Lehtonen, Mikko Kuivaniemi, L. Haarla
This paper investigates how the location of forced oscillation (FO) source affects the resonance phenomenon between the FO and inter-area oscillations. The analysis is performed in a simple two generator system and the full Nordic power system simulation model. The main finding is that when the FO source is moved from the “center of the inter-area oscillation mode” towards the “ends” of the system, the amplification of the FO increases approximately linearly as a function of the voltage angle difference (or electrical distance) from the center. This finding enables an easy evaluation of risks associated with FO sources in different locations. Such information is also valuable generally in transmission system planning and operation.
{"title":"Forced Oscillation and Inter-Area Mode Resonance-Effect of the Location of the Oscillation Source","authors":"Janne Seppänen, M. Lehtonen, Mikko Kuivaniemi, L. Haarla","doi":"10.1109/PESGM48719.2022.9917223","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917223","url":null,"abstract":"This paper investigates how the location of forced oscillation (FO) source affects the resonance phenomenon between the FO and inter-area oscillations. The analysis is performed in a simple two generator system and the full Nordic power system simulation model. The main finding is that when the FO source is moved from the “center of the inter-area oscillation mode” towards the “ends” of the system, the amplification of the FO increases approximately linearly as a function of the voltage angle difference (or electrical distance) from the center. This finding enables an easy evaluation of risks associated with FO sources in different locations. Such information is also valuable generally in transmission system planning and operation.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124025594","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9916778
Jack S. Bryant, B. Mcgrath, Lasantha Gunaruwan Meegahapola, P. Sokolowski
Grid-forming inverters present a promising control philosophy for inverter-dominated power grids. However, further research is required to better understand the modeling and control of such devices, yielding design and performance improve-ments alike. This paper systematically develops a small-signal model predicated upon a state-space framework, accurately capturing dynamics associated with the current and voltage regulators, droop controller, modulation scheme, LCL filter, and grid connection. Participation factor analysis compares and contrasts the modal characteristics of grid-forming and grid-feeding inverter topologies, with the main differences observed in the states contributing to the fastest modes (eigenvalues). Moreover, small-signal analysis of the current and voltage regu-lators' proportional gains demonstrates the latter's significance concerning the grid-forming inverter's stability. Time-domain simulations validate the small-signal model's predictions.
{"title":"Small-Signal Modeling and Stability Analysis of a Droop-Controlled Grid-Forming Inverter","authors":"Jack S. Bryant, B. Mcgrath, Lasantha Gunaruwan Meegahapola, P. Sokolowski","doi":"10.1109/PESGM48719.2022.9916778","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9916778","url":null,"abstract":"Grid-forming inverters present a promising control philosophy for inverter-dominated power grids. However, further research is required to better understand the modeling and control of such devices, yielding design and performance improve-ments alike. This paper systematically develops a small-signal model predicated upon a state-space framework, accurately capturing dynamics associated with the current and voltage regulators, droop controller, modulation scheme, LCL filter, and grid connection. Participation factor analysis compares and contrasts the modal characteristics of grid-forming and grid-feeding inverter topologies, with the main differences observed in the states contributing to the fastest modes (eigenvalues). Moreover, small-signal analysis of the current and voltage regu-lators' proportional gains demonstrates the latter's significance concerning the grid-forming inverter's stability. Time-domain simulations validate the small-signal model's predictions.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129423543","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9917164
F. Milano
The paper introduces the concept of complex frequency. The imaginary part of the complex frequency is the variation with respect of a synchronous reference of the local bus frequency as commonly defined in power system studies. The real part is defined based on the variation of the voltage magnitude. The latter term is crucial for the correct interpretation and analysis of the variation of the frequency at each bus of the network. The paper also develops a set of differential equations that describe the link between complex powers and complex frequencies at network buses in transient conditions. No simplifications are assumed the usual approximations of the models utilized for the transient stability analysis of power systems. A variety of analytical and numerical examples show the applications and potentials of the proposed concept.
{"title":"Complex Frequency","authors":"F. Milano","doi":"10.1109/PESGM48719.2022.9917164","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9917164","url":null,"abstract":"The paper introduces the concept of complex frequency. The imaginary part of the complex frequency is the variation with respect of a synchronous reference of the local bus frequency as commonly defined in power system studies. The real part is defined based on the variation of the voltage magnitude. The latter term is crucial for the correct interpretation and analysis of the variation of the frequency at each bus of the network. The paper also develops a set of differential equations that describe the link between complex powers and complex frequencies at network buses in transient conditions. No simplifications are assumed the usual approximations of the models utilized for the transient stability analysis of power systems. A variety of analytical and numerical examples show the applications and potentials of the proposed concept.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128315849","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 : 2022-07-17DOI: 10.1109/PESGM48719.2022.9916807
Maximiliano F. Ferrari, Emilio C. Piesciorovsky, L. Tolbert
Previous work on real-time simulation of DFIGs have assumed that the generator model is valid over a wide range of operating speeds and for multiple grid voltage unbalances. However, this assumption has not been tested in the literature, which limits the accuracy of results obtained in both simulations and in hardware-in-the-loop (HIL) applications. To address this gap in the literature, this paper presents a preliminary model validation of the DFIG with iron losses and demonstrates the limitations of the model in accurately representing a physical DFIG machine under grid unbalanced operation. This paper implements all the required discrete models for real-time emulation of the DFIG on a field programmable gate array (FPGA), including: the dynamic model of the DFIG, rotor side converter (RSC), grid side converter (GSC), and aerodynamic and mechanical models. Also included are key implementation aspects of the hardware-testbed utilized for the model validation, which consists of a DFIG machine connected to a partial-scaled four-quadrant back-to-back power converter. The DFIG machine models utilized for this research are available to the public and can be accessed in a GitHub repository listed in the references.
{"title":"Real-Time Emulation of Grid-Connected DFIG Wind Energy System with Model Validation from Sub-synchronous to Hyper-synchronous Operation under Unbalanced Conditions","authors":"Maximiliano F. Ferrari, Emilio C. Piesciorovsky, L. Tolbert","doi":"10.1109/PESGM48719.2022.9916807","DOIUrl":"https://doi.org/10.1109/PESGM48719.2022.9916807","url":null,"abstract":"Previous work on real-time simulation of DFIGs have assumed that the generator model is valid over a wide range of operating speeds and for multiple grid voltage unbalances. However, this assumption has not been tested in the literature, which limits the accuracy of results obtained in both simulations and in hardware-in-the-loop (HIL) applications. To address this gap in the literature, this paper presents a preliminary model validation of the DFIG with iron losses and demonstrates the limitations of the model in accurately representing a physical DFIG machine under grid unbalanced operation. This paper implements all the required discrete models for real-time emulation of the DFIG on a field programmable gate array (FPGA), including: the dynamic model of the DFIG, rotor side converter (RSC), grid side converter (GSC), and aerodynamic and mechanical models. Also included are key implementation aspects of the hardware-testbed utilized for the model validation, which consists of a DFIG machine connected to a partial-scaled four-quadrant back-to-back power converter. The DFIG machine models utilized for this research are available to the public and can be accessed in a GitHub repository listed in the references.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128388442","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 : 2022-07-17DOI: 10.1109/pesgm48719.2022.9917247
Cong Chen, Lang Tong, Ye Guo
Pricing multi-interval economic dispatch of electric power under operational uncertainty is considered in this two- part paper. Part I investigates dispatch-following incentives of profit-maximizing generators and shows that, under mild conditions, no uniform-pricing scheme for the rolling-window economic dispatch provides dispatch-following incentives that avoid discriminative out-of-the-market uplifts. A nonuniform pricing mechanism, referred to as the temporal locational marginal pricing (TLMP), is proposed. As an extension of the standard locational marginal pricing (LMP), TLMP takes into account both generation and ramping-induced opportunity costs. It eliminates the need for the out-ofthe- market uplifts and guarantees full dispatch-following incentives regardless of the accuracy of the demand forecasts used in the dispatch. It is also shown that, under TLMP, a price-taking market participant has incentives to bid truthfully with its marginal cost of generation. Part II of the paper extends the theoretical results developed in Part I to more general network settings. It investigates a broader set of performance measures, including the incentives of the truthful revelation of ramping limits, revenue adequacy of the operator, consumer payments, generator profits, and price volatility under the rolling-window dispatch model with demand forecast errors.
{"title":"Pricing Multi-Interval Dispatch under Uncertainty Part I: Dispatch-Following Incentives & Part II: Generalization and Performance","authors":"Cong Chen, Lang Tong, Ye Guo","doi":"10.1109/pesgm48719.2022.9917247","DOIUrl":"https://doi.org/10.1109/pesgm48719.2022.9917247","url":null,"abstract":"Pricing multi-interval economic dispatch of electric power under operational uncertainty is considered in this two- part paper. Part I investigates dispatch-following incentives of profit-maximizing generators and shows that, under mild conditions, no uniform-pricing scheme for the rolling-window economic dispatch provides dispatch-following incentives that avoid discriminative out-of-the-market uplifts. A nonuniform pricing mechanism, referred to as the temporal locational marginal pricing (TLMP), is proposed. As an extension of the standard locational marginal pricing (LMP), TLMP takes into account both generation and ramping-induced opportunity costs. It eliminates the need for the out-ofthe- market uplifts and guarantees full dispatch-following incentives regardless of the accuracy of the demand forecasts used in the dispatch. It is also shown that, under TLMP, a price-taking market participant has incentives to bid truthfully with its marginal cost of generation. Part II of the paper extends the theoretical results developed in Part I to more general network settings. It investigates a broader set of performance measures, including the incentives of the truthful revelation of ramping limits, revenue adequacy of the operator, consumer payments, generator profits, and price volatility under the rolling-window dispatch model with demand forecast errors.","PeriodicalId":388672,"journal":{"name":"2022 IEEE Power & Energy Society General Meeting (PESGM)","volume":"577 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128738404","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：