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Mehdi Abapour
Faculty of Electrical and Computer Engineering, University of Tabriz, 5166616471, Tabriz, Iran

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Review
Published: 02 June 2021 in Sustainable Cities and Society
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In recent years, energy saving has attracted the attention of researchers due to environment, energy, and reliability issues. Energy saving due to these advantages is one of the major steps toward sustainable cities and society. In this regard, the low-voltage section of the distribution system, including buildings and public lighting systems (PLSs), has great energy-saving potential. Accordingly, the present work reviews the potential of different energy-saving options and their environmental impact on buildings of different sectors and PLSs. In addition to direct energy-saving options such as using renewable energy sources and energy-efficient luminaries, available indirect options such as transactive energy, using energy storage systems and demand response programs are reviewed. For both the building and PLS sectors, available control strategies and technologies and related energy and emission saving potential are discussed. The detailed highlights of the previous works associated with the location of each research or experimental study are given in this review study. Finally, the key findings regarding the gap in the literature of the energy saving topic are discussed. This study is influential for policy-makers to take effective actions for energy saving through existing approaches and technologies, and is beneficial for researchers of the energy saving topic.

ACS Style

Omid Sadeghian; Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Jeng Shiun Lim; Fausto Pedro Garcia Marquez. A comprehensive review on energy saving options and saving potential in low voltage electricity distribution networks: Building and public lighting. Sustainable Cities and Society 2021, 72, 103064 .

AMA Style

Omid Sadeghian, Arash Moradzadeh, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Amjad Anvari-Moghaddam, Jeng Shiun Lim, Fausto Pedro Garcia Marquez. A comprehensive review on energy saving options and saving potential in low voltage electricity distribution networks: Building and public lighting. Sustainable Cities and Society. 2021; 72 ():103064.

Chicago/Turabian Style

Omid Sadeghian; Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Jeng Shiun Lim; Fausto Pedro Garcia Marquez. 2021. "A comprehensive review on energy saving options and saving potential in low voltage electricity distribution networks: Building and public lighting." Sustainable Cities and Society 72, no. : 103064.

Journal article
Published: 27 May 2021 in IEEE Systems Journal
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Nowadays, industrial parks play a significant role in the development of electricity market plans, and can thus provide excellent opportunities for market players to actively participate in various electricity markets. The demand response aggregator (DRA) is a major market player that can take advantage of these opportunities. In restructured electricity markets, identifying the consumption patterns of different classes of consumers can be effective in furthering the goals of the DRA. In previous studies on the self-scheduling of the DRA, consumer behavior has not been considered. Such an approach leads to numerous technical problems in the restructured electricity markets. For this purpose, herein, a practical mechanism is presented for executing the self-scheduling process of the DRA by considering the load disaggregation algorithm. The integration of self-scheduling and load disaggregation processes creates a hierarchical optimization problem. The main aim of the constructed hierarchical structure is to find the optimal self-scheduling of the DRA to consciously participate in the electricity markets by identifying the behavior of different consumers. The proposed structure is implemented and evaluated on the industrial park in Saveh, Iran. The time-of-use (TOU) and reward-based demand response (DR) programs are considered as the tools available for the DRA to trade the DR volumes in the day-ahead and balancing electricity markets.

ACS Style

Morteza Zare Oskouei; Sevda Zeinal-Kheiri; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Hasan Mehrjerdi. Optimal Scheduling of Demand Response Aggregators in Industrial Parks Based on Load Disaggregation Algorithm. IEEE Systems Journal 2021, PP, 1 -10.

AMA Style

Morteza Zare Oskouei, Sevda Zeinal-Kheiri, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Hasan Mehrjerdi. Optimal Scheduling of Demand Response Aggregators in Industrial Parks Based on Load Disaggregation Algorithm. IEEE Systems Journal. 2021; PP (99):1-10.

Chicago/Turabian Style

Morteza Zare Oskouei; Sevda Zeinal-Kheiri; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Hasan Mehrjerdi. 2021. "Optimal Scheduling of Demand Response Aggregators in Industrial Parks Based on Load Disaggregation Algorithm." IEEE Systems Journal PP, no. 99: 1-10.

Journal article
Published: 11 May 2021 in IEEE Transactions on Sustainable Energy
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Coordinated operation of several industrial energy hubs (IEHs) to realize local energy management concepts at strategic points like industrial parks has attracted the attention of power grid operators worldwide. Deriving an operational model for integrating a large set of IEHs to trade energy in various markets is a fundamental challenge that has not yet been addressed. In this context, this paper presents an optimal market participation strategy for a virtual energy hub (VEH) consisting of multiple IEHs and industrial consumers. The proposed strategy seeks to answer two questions: (1) how can a VEH operator (VEHO) minimize its operation cost when participating in different energy markets (2) how can ancillary services affect the economic performance of VEH To address these questions, a two-stage robust-stochastic optimization model is proposed with the aim of minimizing the total operation cost of VEH and compensating the operational risks associated with the existing uncertainties considering the operational limits of the power grid. To this aim, the advanced ancillary services, i.e., market-based demand response programs and transactive energy management mechanism are used in line with the optimization problem. Furthermore, the role of the multi-supply facilities is included in the developed strategy to improve VEH flexibility.

ACS Style

Morteza Zare Oskouei; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Mahmood Shafiee; Amjad Anvari-Moghaddam. Strategic Operation of a Virtual Energy Hub with the Provision of Advanced Ancillary Services in Industrial Parks. IEEE Transactions on Sustainable Energy 2021, PP, 1 -1.

AMA Style

Morteza Zare Oskouei, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Mahmood Shafiee, Amjad Anvari-Moghaddam. Strategic Operation of a Virtual Energy Hub with the Provision of Advanced Ancillary Services in Industrial Parks. IEEE Transactions on Sustainable Energy. 2021; PP (99):1-1.

Chicago/Turabian Style

Morteza Zare Oskouei; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Mahmood Shafiee; Amjad Anvari-Moghaddam. 2021. "Strategic Operation of a Virtual Energy Hub with the Provision of Advanced Ancillary Services in Industrial Parks." IEEE Transactions on Sustainable Energy PP, no. 99: 1-1.

Journal article
Published: 30 April 2021 in Sustainability
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Increasing applications of CHP units have turned the problem of finding the best optimization model into a significant subject for scholars. In this respect, this paper is aimed at driving a novel formulation to the multi-objective day-ahead scheduling of CHP units using Bernstein polynomials, which more optimally schedules power and heat generations as well as ramping trajectories. This procedure includes yielding an affine function that closely approximates real-time net-load and generation trajectories, which is demonstrated to have a superior performance to the conventional hourly day-ahead scheduling of CHP units based on discrete-time approximation. The problem of how to handle various objective functions by function space method is also addressed. The simulations conducted on the sample test systems, which consist of CHP systems, thermal and heat-only units, as well as thermal and electrical loads, show that the suggested multi-objective model can perfectly cover the total heat and electrical loads in terms of economic and environmental criteria. More importantly, the results indicate that the accuracy of the proposed approach renders cost saving of 1.67% and emission saving of 1.46% in comparison with the conventional hourly-based model, apart from leading to fewer ramping scarcities in real-time operations.

ACS Style

Elnaz Davoodi; Salar Balaei-Sani; Behnam Mohammadi-Ivatloo; Mehdi Abapour. Flexible Continuous-Time Modeling for Multi-Objective Day-Ahead Scheduling of CHP Units. Sustainability 2021, 13, 5058 .

AMA Style

Elnaz Davoodi, Salar Balaei-Sani, Behnam Mohammadi-Ivatloo, Mehdi Abapour. Flexible Continuous-Time Modeling for Multi-Objective Day-Ahead Scheduling of CHP Units. Sustainability. 2021; 13 (9):5058.

Chicago/Turabian Style

Elnaz Davoodi; Salar Balaei-Sani; Behnam Mohammadi-Ivatloo; Mehdi Abapour. 2021. "Flexible Continuous-Time Modeling for Multi-Objective Day-Ahead Scheduling of CHP Units." Sustainability 13, no. 9: 5058.

Original research paper
Published: 20 April 2021 in IET Renewable Power Generation
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This paper elaborates on optimal scheduling of coordinated power and natural gas (NG) networks in the presence of interconnected energy hubs considering reconfiguration as a flexibility source. With regard to the energy hub system consisting of several generation units, storage and conversion technologies, as well as natural gas‐fired units, the high interdependency between gas and electricity carriers should be captured. The hourly reconfiguration capability is developed for the first time in a multi‐energy system to enhance the optimal power dispatch and gas consumption pattern. The realistic interdependency of electrical and NG grids is investigated by employing the steady‐state Weymouth equation and AC‐power flow model for power and gas networks, respectively. Furthermore, to handle the risk associated with strong uncertainty of wind power, load, and real‐time power price, the conditional value at risk approach is employed. The proposed model is implemented on the integrated test system and simulation results are presented for different cases. The impact of the risk aversion level on operating cost and optimal scheduling of controllable units is examined. Numerical results demonstrate that reconfigurable capability reduces the operational cost up to 7.82%.

ACS Style

Mohammad Hemmati; Mehdi Abapour; Behnam Mohammadi‐Ivatloo; Amjad Anvari‐Moghaddam. Risk‐based optimal operation of coordinated natural gas and reconfigurable electrical networks with integrated energy hubs. IET Renewable Power Generation 2021, 1 .

AMA Style

Mohammad Hemmati, Mehdi Abapour, Behnam Mohammadi‐Ivatloo, Amjad Anvari‐Moghaddam. Risk‐based optimal operation of coordinated natural gas and reconfigurable electrical networks with integrated energy hubs. IET Renewable Power Generation. 2021; ():1.

Chicago/Turabian Style

Mohammad Hemmati; Mehdi Abapour; Behnam Mohammadi‐Ivatloo; Amjad Anvari‐Moghaddam. 2021. "Risk‐based optimal operation of coordinated natural gas and reconfigurable electrical networks with integrated energy hubs." IET Renewable Power Generation , no. : 1.

Journal article
Published: 26 February 2021 in Sustainable Cities and Society
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Microgrids (MGs) are solutions to integrate high shares of variable renewable energy which can contribute to more economical and environmental benefits, as well as improving the energy supply efficiency. One significant potential of MGs is an expanded opportunity to use the waste heating energy from the conversion of the primary fuel (such as natural gas) to generate electricity. The use of waste heat in combined heat and power (CHP)-based MG is more efficient to meet local load and decrease the emission pollution. Hence, this paper elaborates on optimal multi-objective scheduling of CHP-based MG coupled with compressed air energy storage (CAES), renewable energy, thermal energy storage (TES), and demand response programs through shiftable loads, which considers a reconfiguration capability. The embedded CAES, in addition to the charging/discharging scheme, can operate in a simple cycling mode and serve as a generation resource to supply local load in an emergency condition. The daily reconfiguration of MG will introduce a new generation of MG named reconfigurable microgrid (RMG) that offers more flexibility and enhances system reliability. The RMG is coupled with TES to facilitate the integration of the CHP unit that enables the operator to participate in the thermal market, in addition to the power market. The main intents of the proposed multi-objective problem are to minimize the operation cost along with a reduction in carbon emission. The epsilon-constraint technique is used to solve the multi-objective problem while fuzzy decision making is implemented to select an optimal solution among all the Pareto solutions. The electricity prices and wind power generation variation are captured as random variables in the model and the scenario-based stochastic approach is used to handle them. Simulation results prove that the simultaneous integration of multiple technologies in CHP-based RMG decreases the operation cost and emission up to 3 % and 10.28 %, respectively.

ACS Style

Mohammad Hemmati; Mohammad Amin Mirzaei; Mehdi Abapour; Kazem Zare; Behnam Mohammadi-Ivatloo; Hassan Mehrjerdi; Mousa Marzband. Economic-environmental analysis of combined heat and power-based reconfigurable microgrid integrated with multiple energy storage and demand response program. Sustainable Cities and Society 2021, 69, 102790 .

AMA Style

Mohammad Hemmati, Mohammad Amin Mirzaei, Mehdi Abapour, Kazem Zare, Behnam Mohammadi-Ivatloo, Hassan Mehrjerdi, Mousa Marzband. Economic-environmental analysis of combined heat and power-based reconfigurable microgrid integrated with multiple energy storage and demand response program. Sustainable Cities and Society. 2021; 69 ():102790.

Chicago/Turabian Style

Mohammad Hemmati; Mohammad Amin Mirzaei; Mehdi Abapour; Kazem Zare; Behnam Mohammadi-Ivatloo; Hassan Mehrjerdi; Mousa Marzband. 2021. "Economic-environmental analysis of combined heat and power-based reconfigurable microgrid integrated with multiple energy storage and demand response program." Sustainable Cities and Society 69, no. : 102790.

Journal article
Published: 16 February 2021 in IEEE Access
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This paper introduces a transactive market design for a combined heat and power (CHP) based energy hub (hub). The proposed model allows a hub operator to supply the hub’s demands by participating in the day-ahead market and a transactive market with CHPs and also in the real-time market by using a recursive moving window algorithm. The proposed local energy market for a hub operator and CHPs is based on the double auction P2P trading mechanism. The model develops an optimal bidding and offering strategies for CHPs and hub operators, respectively, to achieve optimal transactions. The CHPs may be equipped with boiler unit and heat buffer tank (HBT) beside CHP units. The uncertain nature of the hub’s electrical load, real-time and day-ahead markets prices and wind speed is addressed by using robust optimization. The procedure aimed at minimizing the worst-case CHP-based hub’s demand procurement cost even though flexibly regulating the solution robustness. Further, case studies investigate the economic impact of robustness on the hub’s cost.

ACS Style

Manijeh Alipour; Mehdi Abapour; Sajjad Tohidi; Saeid Gholami Farkoush; Sang-Bong Rhee. Designing Transactive Market for Combined Heat and Power Management in Energy Hubs. IEEE Access 2021, 9, 31411 -31419.

AMA Style

Manijeh Alipour, Mehdi Abapour, Sajjad Tohidi, Saeid Gholami Farkoush, Sang-Bong Rhee. Designing Transactive Market for Combined Heat and Power Management in Energy Hubs. IEEE Access. 2021; 9 (99):31411-31419.

Chicago/Turabian Style

Manijeh Alipour; Mehdi Abapour; Sajjad Tohidi; Saeid Gholami Farkoush; Sang-Bong Rhee. 2021. "Designing Transactive Market for Combined Heat and Power Management in Energy Hubs." IEEE Access 9, no. 99: 31411-31419.

Journal article
Published: 18 January 2021 in IEEE Access
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Integrating microgrids within distribution systems can significantly improve the power system’s reliability while reducing operating costs. However, due to the unintentional disaster conditions, sometimes distribution systems and microgrids cannot support each other, and the microgrids are forced to work in the islanded mode. Accordingly, we developed an optimal resilient scheduling scheme that guarantees networked microgrids (NMGs) reliable operation in the normal and islanding modes. To achieve this aim, the problem is decomposed into day-ahead normal operation (grid-connected) and real-time islanded examination by benders decomposition algorithm perspective. The specified scheme of NMGs in the normal operation will be scrutinized in the real-time islanded mode. According to the benders decomposition theory, the scheduling of NMGs would be revised in the next iteration if the current schedule is not feasible for possible real-time islanding conditions. The status of thermal units, charging, and discharging of energy storage systems respecting their other constraints are changed depending on the type and severity of mismatches between generation and demand. Three different interconnection topologies are tested for assessing the performance of the proposed method and the impact of transaction energy between NMGs on that. Numerical simulations illustrate the advantages of the proposed scheme and explain its merits.

ACS Style

Hadi Safari Fesagandis; Mehdi Jalali; Kazem Zare; Mehdi Abapour; Hadis Karimipour. Resilient Scheduling of Networked Microgrids Against Real-Time Failures. IEEE Access 2021, 9, 21443 -21456.

AMA Style

Hadi Safari Fesagandis, Mehdi Jalali, Kazem Zare, Mehdi Abapour, Hadis Karimipour. Resilient Scheduling of Networked Microgrids Against Real-Time Failures. IEEE Access. 2021; 9 ():21443-21456.

Chicago/Turabian Style

Hadi Safari Fesagandis; Mehdi Jalali; Kazem Zare; Mehdi Abapour; Hadis Karimipour. 2021. "Resilient Scheduling of Networked Microgrids Against Real-Time Failures." IEEE Access 9, no. : 21443-21456.

Original research
Published: 02 January 2021 in Journal of Ambient Intelligence and Humanized Computing
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In recent years, the introduction of practical and useful solutions to solve the non-intrusive load monitoring (NILM) as one of the sub-sectors of energy management has posed many challenges. In this paper, an effective and applicable solution based on deep learning called convolutional neural network (CNN) is employed for this purpose. The proposed method with the layer-to-layer structure and extraction of features in the power consumption (PC) curves of each household appliances will be able to detect and distinguish the type of electrical appliances (EAs). Likewise, the load disaggregation for the total home PC will be based on identifying the PC patterns of each EA. To do this, experimental evaluation of reference energy data disaggregation dataset (REDD) related to real-world data and measurement at low frequency is used. The PC curves of each EA are used as input data for training and testing the network. After initial training and testing by the PC data of EAs, the total PC of building obtained from the smart meter are used as input for each network in order to load disaggregation. The trained networks prove to be able to disaggregate the total PC for REDD houses 1, 2, 3, and 4 with a 96.17% mean accuracy. The presented results show the precision and efficiency of the suggested technique for solving NILM problems compared to other used methods.

ACS Style

Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Saeid Gholami Farkoush; Sang-Bong Rhee. A practical solution based on convolutional neural network for non-intrusive load monitoring. Journal of Ambient Intelligence and Humanized Computing 2021, 1 -15.

AMA Style

Arash Moradzadeh, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Amjad Anvari-Moghaddam, Saeid Gholami Farkoush, Sang-Bong Rhee. A practical solution based on convolutional neural network for non-intrusive load monitoring. Journal of Ambient Intelligence and Humanized Computing. 2021; ():1-15.

Chicago/Turabian Style

Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Saeid Gholami Farkoush; Sang-Bong Rhee. 2021. "A practical solution based on convolutional neural network for non-intrusive load monitoring." Journal of Ambient Intelligence and Humanized Computing , no. : 1-15.

Journal article
Published: 03 November 2020 in IEEE Transactions on Power Electronics
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In order to approach a voltage of high magnitude in Photovoltaic (PV) application several PV modules are connected in series to form a PV string, then the voltage of PV string is converted to an ac voltage through an H-bridge inverter. This system causes harmful harmonics, brings about leakage current, and increases the voltage stress of the components. To tackle the issue, this paper proposes a new switched-capacitor-based multilevel inverter topology that uses series-connected dc sources as the input dc source and generates a staircase ac voltage of high quality and mitigates the leakage current. The proposed topology can be constructed as a three-phase inverter as well, in the three-phase configuration all the phases are connected to only one series-connected PV module or dc sources. Simulation and experimental results are provided to validate the proposed topology

ACS Style

Hossein Khoun Jahan; Mehdi Abapour. Switched-Capacitor-Based Multilevel Inverter for Grid-Connected Photovoltaic Application. IEEE Transactions on Power Electronics 2020, 36, 10317 -10329.

AMA Style

Hossein Khoun Jahan, Mehdi Abapour. Switched-Capacitor-Based Multilevel Inverter for Grid-Connected Photovoltaic Application. IEEE Transactions on Power Electronics. 2020; 36 (9):10317-10329.

Chicago/Turabian Style

Hossein Khoun Jahan; Mehdi Abapour. 2020. "Switched-Capacitor-Based Multilevel Inverter for Grid-Connected Photovoltaic Application." IEEE Transactions on Power Electronics 36, no. 9: 10317-10329.

Journal article
Published: 09 October 2020 in Sustainability
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Coordinated multi-carrier energy systems with natural gas and electricity energies provide specific opportunities to improve energy efficiency and flexibility of the energy supply. The interdependency of electricity and natural gas networks faces multiple challenges from power and gas flow in corresponding feeders and pipes and connection points between two infrastructures’ points of view. However, the energy hub concepts as the fundamental concept of multi-carrier energy systems with multiple conversion, storage, and generation facilities can be considered as a connection point between electricity and gas grids. Hence, this paper proposes an optimal operation of coordinated gas and electricity distribution networks by considering interconnected energy hubs. The proposed energy hub is equipped with combined heat and power units, a boiler, battery energy storage, a heat pump, and a gas-fired unit to meet the heating and electrical load demands. The proposed model is formulated as a two-stage scenario-based stochastic model aiming to minimize total operational cost considering wind energy, electrical load, and real-time power price uncertainties. The proposed integrated energy system can participate in real-time and day-ahead power markets, as well as the gas market, to purchase its required energy. The AC-power flow and Weymouth equation are extended to describe power and gas flow in feeders and gas pipelines, respectively. Therefore, a realistic model for the integrated electricity and gas grids considering coupling constraints is satisfied. The proposed model is tested on the integrated energy system and consists of a 33-bus electrical network and a 6-node gas grid with multiple interconnected energy hubs, where the numerical results reveal the effectiveness of the proposed model.

ACS Style

Mohammad Hemmati; Mehdi Abapour; Behnam Mohammadi-Ivatloo; Amjad Anvari-Moghaddam. Optimal Operation of Integrated Electrical and Natural Gas Networks with a Focus on Distributed Energy Hub Systems. Sustainability 2020, 12, 8320 .

AMA Style

Mohammad Hemmati, Mehdi Abapour, Behnam Mohammadi-Ivatloo, Amjad Anvari-Moghaddam. Optimal Operation of Integrated Electrical and Natural Gas Networks with a Focus on Distributed Energy Hub Systems. Sustainability. 2020; 12 (20):8320.

Chicago/Turabian Style

Mohammad Hemmati; Mehdi Abapour; Behnam Mohammadi-Ivatloo; Amjad Anvari-Moghaddam. 2020. "Optimal Operation of Integrated Electrical and Natural Gas Networks with a Focus on Distributed Energy Hub Systems." Sustainability 12, no. 20: 8320.

Journal article
Published: 07 October 2020 in Mathematics
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The cascaded multilevel inverter (CMI) is one type of common inverter in industrial applications. This type of inverter can be synthesized either as a symmetric configuration with several identical H-bridge (HB) cells or as an asymmetric configuration with non-identical HB cells. In photovoltaic (PV) applications with the CMI, the PV modules can be used to replace the isolated dc sources; however, this brings inter-module leakage currents. To tackle the issue, the single-source CMI is preferred. Furthermore, in a grid-tied PV system, the main constraint is the capacitive leakage current. This problem can be addressed by providing a common ground, which is shared by PV modules and the ac grid. This paper thus proposes a topology that fulfills the mentioned requirements and thus, CMI is a promising inverter with wide-ranging industrial uses, such as PV applications. The proposed CMI topology also features high boosting capability, fault current limiting, and a transformerless configuration. To demonstrate the capabilities of this CMI, simulations and experimental results are provided.

ACS Style

Hossein Khoun Jahan; Naser Vosoughi Kurdkandi; Mehdi Abapour; Kazem Zare; Seyed Hossein Hosseini; Yongheng Yang; Frede Blaabjerg. Common-Ground-Type Single-Source High Step-Up Cascaded Multilevel Inverter for Transformerless PV Applications. Mathematics 2020, 8, 1716 .

AMA Style

Hossein Khoun Jahan, Naser Vosoughi Kurdkandi, Mehdi Abapour, Kazem Zare, Seyed Hossein Hosseini, Yongheng Yang, Frede Blaabjerg. Common-Ground-Type Single-Source High Step-Up Cascaded Multilevel Inverter for Transformerless PV Applications. Mathematics. 2020; 8 (10):1716.

Chicago/Turabian Style

Hossein Khoun Jahan; Naser Vosoughi Kurdkandi; Mehdi Abapour; Kazem Zare; Seyed Hossein Hosseini; Yongheng Yang; Frede Blaabjerg. 2020. "Common-Ground-Type Single-Source High Step-Up Cascaded Multilevel Inverter for Transformerless PV Applications." Mathematics 8, no. 10: 1716.

Research paper
Published: 16 July 2020 in Iranian Journal of Science and Technology, Transactions of Electrical Engineering
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Despite distributed generations (DGs) advantages, the presence of them can cause glitches in distribution networks. One of the typical glitches is a mismatched fuse and recloser in temporary short circuits, which is often remedied by fault current limiter (FCL). By calculating the expected benefits to distribution companies (DISCOs) in various value of loss load scenarios, once the uncertainty output of DGs is considered, this paper examines the effectiveness of FCLs in solving drawbacks and improving reliability. FCL can improve network reliability in one of two ways: a) the FCL can reduce the magnitude of fault current, thereby decreasing the failure rate of protective devices, b) the FCL can correct a mismatched fuse and recloser, resulting in a lower energy not supplied (ENS) rate. The present paper uses the biogeography-based optimization method to measure optimal FCL impedance in terms of maximizing the DISCO’s benefit after FCL installation. Using simulated performance on a test distribution system, FCL network penetration is founded to resolve the identified problem by improving the ENS rate.

ACS Style

S. Ghaemi; M. Nazari-Heris; M. Abapour. Reliability Impact Analysis of Fault Current Limiters of Distribution Network Under Protection Miscoordination Due to Distributed Generations. Iranian Journal of Science and Technology, Transactions of Electrical Engineering 2020, 45, 171 -182.

AMA Style

S. Ghaemi, M. Nazari-Heris, M. Abapour. Reliability Impact Analysis of Fault Current Limiters of Distribution Network Under Protection Miscoordination Due to Distributed Generations. Iranian Journal of Science and Technology, Transactions of Electrical Engineering. 2020; 45 (1):171-182.

Chicago/Turabian Style

S. Ghaemi; M. Nazari-Heris; M. Abapour. 2020. "Reliability Impact Analysis of Fault Current Limiters of Distribution Network Under Protection Miscoordination Due to Distributed Generations." Iranian Journal of Science and Technology, Transactions of Electrical Engineering 45, no. 1: 171-182.

Journal article
Published: 14 July 2020 in Energies
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Recently, with the penetration of numerous Distributed Energy Resources (DER) in Smart Distribution Networks (SDN), Local Transactive Markets have emerged. Exchanging energy between all participants of local markets results in the satisfaction of producers and consumers. Based on these issues, this study provides a novel framework for the participation of SDN-independent entities in wholesale and local electricity markets simultaneously. In this regard, the considered system’s players, namely Distribution System Operator (DSO) and DER Aggregator (AG), take part within local as well as wholesale markets in two-day ahead and real-time stages. Moreover, to deal with the inherent conflict between the existing players’ interests, a Stackelberg game-based technique is proposed. In the raised competition, the leader, DSO, attempts to minimize its operating costs, while the follower, DER AG, tends to maximize its profit. Therefore, actors’ actions choices within both markets are made non-cooperatively. On the other hand, to handle the uncertain nature of stochastic parameters in the depicted problem, Monte Carlo Simulation (MCS), together with a fast backward/forward scenario reduction approach, is exploited. Ultimately, to evaluate the efficiency of the proposed scheme, two different case studies, with and without considering the competitive environment, are implemented on a modified IEEE-33 bus SDN.

ACS Style

Sara Haghifam; Kazem Zare; Mehdi Abapour; Gregorio Muñoz-Delgado; Javier Contreras. A Stackelberg Game-Based Approach for Transactive Energy Management in Smart Distribution Networks. Energies 2020, 13, 3621 .

AMA Style

Sara Haghifam, Kazem Zare, Mehdi Abapour, Gregorio Muñoz-Delgado, Javier Contreras. A Stackelberg Game-Based Approach for Transactive Energy Management in Smart Distribution Networks. Energies. 2020; 13 (14):3621.

Chicago/Turabian Style

Sara Haghifam; Kazem Zare; Mehdi Abapour; Gregorio Muñoz-Delgado; Javier Contreras. 2020. "A Stackelberg Game-Based Approach for Transactive Energy Management in Smart Distribution Networks." Energies 13, no. 14: 3621.

Journal article
Published: 03 July 2020 in IEEE Access
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Low voltage ride through (LVRT) is one of the indispensable issues of recent decade in the context of grid codes. LVRT stands for the ability of a generation facility to stay connected during the voltage dip. Despite the numerous discussions in recent works, but they mostly concentrate on the LVRT-based control of distributed energy resources (DERs) integrated into a microgrid and its improvement. However, what has been hidden and not addressed any more yet is an index to measure the LVRT capability of a DER-penetrated distribution network (DPDN) under different voltage sags. This takes precedence when we want to evaluate the LVRT capability of DPDNs with consideration of various LVRT categories of DERs mandated in IEEE 1547 standard. This paper introduces a general framework for LVRT assessment of a DPDN by solving a system of differential algebraic equations (DAEs). Then expected LVRT capability of a DPDN is evaluated by a proposed LVRT index through the implementation of Monte Carlo simulation technique.

ACS Style

Pouya Salyani; Kazem Zare; Mehdi Abapour; Amin Safari; Miadreza Shafie-Khah. A General Mathematical Model for LVRT Capability Assessment of DER-Penetrated Distribution Networks. IEEE Access 2020, 8, 125521 -125533.

AMA Style

Pouya Salyani, Kazem Zare, Mehdi Abapour, Amin Safari, Miadreza Shafie-Khah. A General Mathematical Model for LVRT Capability Assessment of DER-Penetrated Distribution Networks. IEEE Access. 2020; 8 ():125521-125533.

Chicago/Turabian Style

Pouya Salyani; Kazem Zare; Mehdi Abapour; Amin Safari; Miadreza Shafie-Khah. 2020. "A General Mathematical Model for LVRT Capability Assessment of DER-Penetrated Distribution Networks." IEEE Access 8, no. : 125521-125533.

Journal article
Published: 26 June 2020 in IEEE Access
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This paper proposes a two-stage robust-stochastic framework to evaluate the effect of the battery-based energy storage transport (BEST) system in a day-ahead market-clearing model. The model integrates the energy market-clearing process with a train routing problem, where a time-space network is used to describe the limitations of the rail transport network (RTN). Likewise, a price-sensitive shiftable (PSS) demand bidding approach is applied to increase the flexibility of the power grid operation and reduce carbon emissions in the system. The main objective of the proposed model is to determine the optimal hourly location, charge/discharge scheduling of the BEST system, power dispatch of thermal units, flexible loads scheduling as well as finding the locational marginal price (LMP) considering the daily carbon emission limit of thermal units. The proposed two-stage framework allows the market operator to differentiate between the risk level of all existing uncertainties and achieve a more flexible decision-making model. The operator can modify the conservatism degree of the market-clearing using a non-probabilistic method based on info-gap decision theory (IGDT), to reduce the effect of wind power fluctuations in real-time. In contrast, a risk-neutral-based stochastic technique is used to meet power demand uncertainty. The results of the proposed mixed-integer linear programming (MILP) problem, confirm the potential of BEST and PSS demand in decreasing the LMP, line congestion, carbon emission, and daily operation cost.

ACS Style

Mohammad Amin Mirzaei; Mohammad Hemmati; Kazem Zare; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Mousa Marzband; Ali Farzamnia. Two-Stage Robust-Stochastic Electricity Market Clearing Considering Mobile Energy Storage in Rail Transportation. IEEE Access 2020, 8, 121780 -121794.

AMA Style

Mohammad Amin Mirzaei, Mohammad Hemmati, Kazem Zare, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Mousa Marzband, Ali Farzamnia. Two-Stage Robust-Stochastic Electricity Market Clearing Considering Mobile Energy Storage in Rail Transportation. IEEE Access. 2020; 8 (99):121780-121794.

Chicago/Turabian Style

Mohammad Amin Mirzaei; Mohammad Hemmati; Kazem Zare; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Mousa Marzband; Ali Farzamnia. 2020. "Two-Stage Robust-Stochastic Electricity Market Clearing Considering Mobile Energy Storage in Rail Transportation." IEEE Access 8, no. 99: 121780-121794.

Journal article
Published: 21 June 2020 in Journal of Cleaner Production
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Transactive energy as an emerging approach and sustainable technology can provide an exceptional opportunity for microgrids to exchange energy with each other for greater benefits in the cluster mode. In this mode of operation, some collective and individual interests can be realized for the microgrids based on transactive energy management. This paper proposes mathematical models for microgrid clusters using a transactive energy structure to manage energy exchange in the smart grid. In order to make an informed decision for the operation of microgrid clusters, chance-constrained programming is employed to consider the uncertainties in balancing collective and individual interests under the transactive energy management. In this research, sixteen commercial microgrids are considered in the process of evaluating the efficiency of the proposed models using the chance-constrained programming method. Simulation results prove the effectiveness of the transactive energy approach accompanying the implementation of chance-constrained programming in energy management of the microgrid clusters.

ACS Style

Mohammadreza Daneshvar; Behnam Mohammadi-Ivatloo; Somayeh Asadi; Amjad Anvari-Moghaddam; Mohammad Rasouli; Mehdi Abapour; Gevork B. Gharehpetian. Chance-constrained models for transactive energy management of interconnected microgrid clusters. Journal of Cleaner Production 2020, 271, 122177 .

AMA Style

Mohammadreza Daneshvar, Behnam Mohammadi-Ivatloo, Somayeh Asadi, Amjad Anvari-Moghaddam, Mohammad Rasouli, Mehdi Abapour, Gevork B. Gharehpetian. Chance-constrained models for transactive energy management of interconnected microgrid clusters. Journal of Cleaner Production. 2020; 271 ():122177.

Chicago/Turabian Style

Mohammadreza Daneshvar; Behnam Mohammadi-Ivatloo; Somayeh Asadi; Amjad Anvari-Moghaddam; Mohammad Rasouli; Mehdi Abapour; Gevork B. Gharehpetian. 2020. "Chance-constrained models for transactive energy management of interconnected microgrid clusters." Journal of Cleaner Production 271, no. : 122177.

Journal article
Published: 05 June 2020 in Energy
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This article proposes a novel short-term decision-making model for electricity retailers within the electricity market and in the presence of Demand Response Aggregators (DRA). In this framework, retailers provide their required energy through the Day-ahead market, Real-time market and forward bilateral contracts. On the other hand, retailers participate in demand response (DR) programs based on the DRA's DR offers to maximize their benefits. In this study, to cope with the uncertainty, the two-stage stochastic programming scheme is utilized. In the first stage, the participation of retailers in the Day-ahead market, as well as power purchased from the forward contracts are decided. In the second stage, the power exchanged with the Real-time market, and the DRA are determined after the realization of stochastic parameters. On the contrary, the DRA enhances its profit through submitting offers to retailers for two DR options. For solving the problem, a strategy based on the Game Theory, the Bi-Level stochastic programming approach is exploited to maximize the profit of both players in a competitive environment. The model is turned into a Single-Level problem by substituting the lower-level with its Karush–Kuhn–Tucker conditions. Finally, merits of the presented method are illustrated in a typical case study.

ACS Style

Mojtaba Dadashi; Sara Haghifam; Kazem Zare; Mahmoud-Reza Haghifam; Mehdi Abapour. Short-term scheduling of electricity retailers in the presence of Demand Response Aggregators: A two-stage stochastic Bi-Level programming approach. Energy 2020, 205, 117926 .

AMA Style

Mojtaba Dadashi, Sara Haghifam, Kazem Zare, Mahmoud-Reza Haghifam, Mehdi Abapour. Short-term scheduling of electricity retailers in the presence of Demand Response Aggregators: A two-stage stochastic Bi-Level programming approach. Energy. 2020; 205 ():117926.

Chicago/Turabian Style

Mojtaba Dadashi; Sara Haghifam; Kazem Zare; Mahmoud-Reza Haghifam; Mehdi Abapour. 2020. "Short-term scheduling of electricity retailers in the presence of Demand Response Aggregators: A two-stage stochastic Bi-Level programming approach." Energy 205, no. : 117926.

Journal article
Published: 03 June 2020 in Energies
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Yearly generation maintenance scheduling (GMS) of generation units is important in each system such as combined heat and power (CHP)-based systems to decrease sudden failures and premature degradation of units. Imposing repair costs and reliability deterioration of system are the consequences of ignoring the GMS program. In this regard, this research accomplishes GMS inside CHP-based systems in order to determine the optimal intervals for predetermined maintenance required duration of CHPs and other units. In this paper, cost minimization is targeted, and violation of units’ technical constraints like feasible operation region of CHPs and power/heat demand balances are avoided by considering related constraints. Demand-response-based short-term generation scheduling is accomplished in this paper considering the maintenance intervals obtained in the long-term plan. Numerical simulation is performed and discussed in detail to evaluate the application of the suggested mixed-integer quadratic programming model that implemented in the General Algebraic Modeling System software package for optimization. Numerical simulation is performed to justify the model effectiveness. The results reveal that long-term maintenance scheduling considerably impacts short-term generation scheduling and total operation cost. Additionally, it is found that the demand response is effective from the cost perspective and changes the generation schedule.

ACS Style

Omid Sadeghian; Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Fausto Pedro Garcia Marquez. Generation Units Maintenance in Combined Heat and Power Integrated Systems Using the Mixed Integer Quadratic Programming Approach. Energies 2020, 13, 2840 .

AMA Style

Omid Sadeghian, Arash Moradzadeh, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Fausto Pedro Garcia Marquez. Generation Units Maintenance in Combined Heat and Power Integrated Systems Using the Mixed Integer Quadratic Programming Approach. Energies. 2020; 13 (11):2840.

Chicago/Turabian Style

Omid Sadeghian; Arash Moradzadeh; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Fausto Pedro Garcia Marquez. 2020. "Generation Units Maintenance in Combined Heat and Power Integrated Systems Using the Mixed Integer Quadratic Programming Approach." Energies 13, no. 11: 2840.

Journal article
Published: 18 May 2020 in Sustainable Cities and Society
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Nowadays with the development of smart appliances in the residential sector, home subscribers can play a key role in energy markets. These appliances in the form of responsive loads have a considerable impact on peak load demand. The use of responsive loads in the optimal coordination with plug-in hybrid electric vehicles (PHEVs) and renewable energy sources (RESs) is an evolved strategy to effectively implement demand response programs (DRPs). In this study, an energy-sharing framework in coordination with DRPs is proposed for residential buildings. The proposed structure seeks to achieve maximum profit for residential customers as well as to decrease the peak load demand by participating in DRPs. To this end, a novel ability of PHEV to share energy between the user’s home and workplace is presented initially. The power transfer between the two areas by PHEV can help to manage the peak load demand and to increase customers’ benefit, while it can be used as spinning reserve in peak intervals. Moreover, the proposed structure is designed based on the residential buildings’ classification in terms of the buildings’ daily activity schedule. In addition, the load management software under the Internet of Things (IoT) technology is constructed to manage smart appliances’ behavior automatically. Analytical analysis is conducted on a sample residential customer load profile. Results show that the proposed method can effectively reduce peak load demand and electrical energy usage.

ACS Style

Morteza Zare Oskouei; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Hasan Mehrjerdi. Practical implementation of residential load management system by considering vehicle-for-power transfer: Profit analysis. Sustainable Cities and Society 2020, 60, 102144 .

AMA Style

Morteza Zare Oskouei, Behnam Mohammadi-Ivatloo, Mehdi Abapour, Amjad Anvari-Moghaddam, Hasan Mehrjerdi. Practical implementation of residential load management system by considering vehicle-for-power transfer: Profit analysis. Sustainable Cities and Society. 2020; 60 ():102144.

Chicago/Turabian Style

Morteza Zare Oskouei; Behnam Mohammadi-Ivatloo; Mehdi Abapour; Amjad Anvari-Moghaddam; Hasan Mehrjerdi. 2020. "Practical implementation of residential load management system by considering vehicle-for-power transfer: Profit analysis." Sustainable Cities and Society 60, no. : 102144.